-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: keymaster@town.hall.org Originator-Key-Asymmetric: MFkwCgYEVQgBAQICAgADSwAwSAJBALeWW4xDV4i7+b6+UyPn5RtObb1cJ7VkACDq pKb9/DClgTKIm08lCfoilvi9Wl4SODbR1+1waHhiGmeZO8OdgLUCAwEAAQ== MIC-Info: RSA-MD5,RSA, mLPbgEqe4Iq43wNacQ/QSG0OGbG3VlaCb9pkahDDGyfg9/8JL7NilX48CZJxvUay +/L5IL+fistiSoMbWs51zQ== 0000890566-94-000092.txt : 19940325 0000890566-94-000092.hdr.sgml : 19940325 ACCESSION NUMBER: 0000890566-94-000092 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 23 CONFORMED PERIOD OF REPORT: 19931231 FILED AS OF DATE: 19940323 FILER: COMPANY DATA: COMPANY CONFORMED NAME: ENRON OIL & GAS CO CENTRAL INDEX KEY: 0000821189 STANDARD INDUSTRIAL CLASSIFICATION: 0000 IRS NUMBER: 470684736 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 34 SEC FILE NUMBER: 001-09743 FILM NUMBER: 94517518 BUSINESS ADDRESS: STREET 1: 1400 SMITH ST STREET 2: P.O. BOX 1188 CITY: HOUSTON STATE: TX ZIP: 77251 BUSINESS PHONE: 7138536161 10-K 1 ANNUAL REPORT SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D. C. 20549 FORM 10-K ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE FISCAL YEAR ENDED DECEMBER 31, 1993 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934 COMMISSION FILE NUMBER: 1-9743 ENRON OIL & GAS COMPANY (EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER) DELAWARE 47-0684736 (STATE OR OTHER JURISDICTION (I.R.S. EMPLOYER OF INCORPORATION OR ORGANIZATION) IDENTIFICATION NO.) 1400 SMITH STREET, HOUSTON, TEXAS 77002-7337 (ADDRESS OF PRINCIPAL EXECUTIVE OFFICES) (ZIP CODE) REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE: 713-853-6161 SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT: TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED Common Stock, without par value New York Stock Exchange SECURITIES REGISTERED PURSUANT TO SECTION 12(G) OF THE ACT: None Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes /X/ No / /. Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. /X/ Aggregate market value of the voting stock held by non-affiliates of the registrant, based on the closing sale price in the daily composite list for transactions on the New York Stock Exchange on March 1, 1994 was $665,277,983. As of March 1, 1994, there were 79,920,000 shares of the registrant's Common Stock, without par value, outstanding. DOCUMENTS INCORPORATED BY REFERENCE. Certain portions of the registrant's definitive Proxy Statement for the May 3, 1994 Annual Meeting of Shareholders ('Proxy Statement') are incorporated in Part III by reference. TABLE OF CONTENTS PART I PAGE Item 1. Business----------------------------- 1 General-------------------------- 1 Business Segments---------------- 1 Exploration and Production------- 1 Marketing------------------------ 3 Wellhead Volumes and Prices, and Lease and Well Expenses-------- 5 Other Natural Gas Marketing Volumes and Prices------------- 6 Competition---------------------- 6 Regulation----------------------- 6 Relationship Between the Company and Enron Corp.---------------- 9 Other Matters-------------------- 11 Current Executive Officers of the Registrant--------------------- 13 Item 2. Properties--------------------------- 14 Oil and Gas Exploration and Production Properties and Reserves----------------------- 14 Item 3. Legal Proceedings-------------------- 17 Item 4. Submission of Matters to a Vote of Security Holders--------------------- 17 PART II Item 5. Market for the Registrant's Common Equity and Related Shareholder Matters---------------------------- 18 Item 6. Selected Financial Data-------------- 19 Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations---------------------- 20 Item 8. Financial Statements and Supplementary Data------------------- 27 Item 9. Disagreements on Accounting and Financial Disclosure----------------- 27 PART III Item 10. Directors and Executive Officers of the Registrant----------------------- 27 Item 11. Executive Compensation--------------- 27 Item 12. Security Ownership of Certain Beneficial Owners and Management------------------------- 27 Item 13. Certain Relationships and Related Transactions------------------------- 27 PART IV Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K-------------------------------- 28 i PART I ITEM 1. BUSINESS GENERAL Enron Oil & Gas Company (the 'Company'), a Delaware corporation, is engaged in the exploration for, and the development and production of, natural gas and crude oil primarily in major producing basins in the United States and, to a lesser extent, in Canada, Trinidad and selected other international areas. At December 31, 1993, the Company's estimated net proved natural gas reserves were 1,772 billion cubic feet ('Bcf') and estimated net proved crude oil, condensate and natural gas liquids reserves were 20.9 million barrels ('MMBbl'). (See 'Supplemental Information to Consolidated Financial Statements'). At such date, approximately 78% of the Company's reserves (on a natural gas equivalent basis) was located in the United States, 16% in Canada and 6% in Trinidad. As of December 31, 1993, the Company employed approximately 690 persons. The Company's core areas are the Big Piney area in Wyoming, South Texas primarily centered in the Lobo Trend area, the Matagorda Trend area located in federal waters offshore Texas and the Canyon Trend located in West Texas. The Company's other domestic natural gas and crude oil producing properties are located primarily in other areas of Texas, Utah, New Mexico, Oklahoma and California. The Company also has natural gas and crude oil producing properties located in western Canada, primarily in the provinces of Alberta, Saskatchewan and Manitoba, and in Trinidad. At December 31, 1993, 95% of the Company's proved domestic reserves (on a natural gas equivalent basis) was natural gas and 5% was crude oil, condensate and natural gas liquids. A substantial portion of the Company's natural gas reserves is in long-lived fields with well established production histories. The opportunity exists to increase production in many of these fields through infill drilling. Enron Corp. currently owns 80% of the outstanding common stock of the Company. (See 'Relationship Between the Company and Enron Corp.'). Unless the context otherwise requires, all references herein to the Company include Enron Oil & Gas Company, its predecessors and subsidiaries. Unless the context otherwise requires, all references herein to Enron Corp. include Enron Corp., its predecessors and affiliates, other than the Company and its subsidiaries. With respect to information on the Company's working interest in wells or acreage, 'net' oil and gas wells or acreage are determined by multiplying 'gross' oil and gas wells or acreage by the Company's working interest in the wells or acreage. Unless otherwise defined, all references to wells are gross. BUSINESS SEGMENTS The Company's operations are all natural gas and crude oil exploration and production related. Accordingly, such operations are classified as one business segment. EXPLORATION AND PRODUCTION The Company's six principal U.S. producing areas are the Big Piney area, South Texas area, Matagorda Trend area, Canyon Trend area, Pitchfork Ranch field and Vernal area. Properties in these areas comprised approximately 76% of the Company's domestic reserves (on a natural gas equivalent basis) and 83% of the Company's maximum domestic net natural gas deliverability as of December 31, 1993 and are substantially all operated by the Company. The Company also has operations in Canada and in Trinidad and is conducting exploration in selected other international areas. BIG PINEY AREA. The Company's largest reserve accumulation is located in the Big Piney area in Sublette and Lincoln counties in southwestern Wyoming. The Company is the holder of the largest productive acreage base in this area, with approximately 200,000 net acres under lease directly within field limits. A portion of the natural gas production from new wells drilled during 1991 and 1992 on the Company's leases in the Big Piney area is classified as tight formation natural gas. (See 'Other 1 Matters - Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). The Company operates approximately 461 natural gas wells in this area in which it owns a 91% average working interest. Production from the area net to the Company averaged 126 million cubic feet ('MMcf') per day of natural gas and 1.4 thousand barrels ('MBbl') per day of crude oil, condensate, and natural gas liquids in 1993. At December 31, 1993, maximum natural gas deliverability net to the Company was approximately 138 MMcf per day. The current principal producing intervals are the Frontier and Mesaverde formations. The Frontier formation, which occurs at 6,500-10,000 feet, contains approximately 66% of the Company's current Big Piney reserves. The Company drilled 48 wells in the Big Piney area in 1993 and anticipates an active drilling program will continue for several years. SOUTH TEXAS AREA. The Company's activities in South Texas are focused in the Wilcox, Expanded Wilcox, Frio and Lobo producing horizons. The primary area of activity is in the Lobo Trend which occurs primarily in Webb and Zapata counties. The Company operates approximately 625 wells in the South Texas area. Production is primarily from the Lobo sand of the Wilcox formation at depths ranging from 7,000 to 11,000 feet. The Company has approximately 260,000 acres under lease in this area and a majority of the natural gas production from new wells drilled during 1991 and 1992 on Company leases in the South Texas Lobo area is classified as tight formation natural gas. (See 'Other Matters - Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). Natural gas sales net to the Company averaged 225 MMcf per day in 1993. At December 31, 1993, maximum natural gas deliverability net to the Company was approximately 250 MMcf per day. The Company drilled 104 wells in the South Texas area in 1993 and anticipates an active drilling program will continue for several years. MATAGORDA TREND AREA. The Company has an interest in several fields in the Matagorda Trend area, located 20 miles south of Port O'Connor, Texas in federal waters. The Company has a 78% working interest in Block 638 and a 92% working interest in Block 620. In Matagorda Blocks 555, 556, 700 and 713, the Company has an approximate 70%, 50%, 62% and 64% working interest, respectively. In addition, the Company has an approximate 82% and 50% working interest in Mustang Island Blocks 758 and 784, respectively. The Company operates all of the offshore tracts mentioned above. Natural gas sales from these areas net to the Company averaged 59 MMcf per day in 1993. At December 31, 1993, maximum natural gas deliverability net to the Company from these blocks was approximately 76 MMcf per day. The Company expects to maintain an active drilling program in the Gulf of Mexico during 1994. CANYON TREND AREA. The Company has added approximately 90,000 acres in this area during the last five years. Activities have been concentrated in Sutton, Crockett and Terrell Counties, Texas where the Company drilled 324 natural gas wells during the period 1991 through 1993. The Company operates approximately 500 natural gas wells in this area in which it owns a 95% average working interest. Production is from the Canyon sands and Strawn limestone at depths from 5,500 to 9,500 feet. At December 31, 1993, maximum natural gas deliverability net to the Company was approximately 70 MMcf per day. The Company expects to maintain an active drilling program in the Canyon Trend area during 1994. (See 'Other Matters - Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). PITCHFORK RANCH FIELD. The Pitchfork Ranch field located in Lea County, New Mexico, produces primarily from the Bone Spring, Atoka and Morrow formations. In 1993, natural gas sales net to the Company averaged 44 MMcf per day. At December 31, 1993, maximum natural gas deliverability net to the Company was approximately 46 MMcf per day. During 1993, the Company significantly increased reserves and deliverability through drilling and workovers. The Company expects to maintain an active drilling program in this field during 1994. (See 'Other Matters - Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). VERNAL AREA. In the Vernal area, located primarily in Uintah County, Utah, the Company operates approximately 187 producing wells and presently controls approximately 75,000 net acres. A 2 majority of the natural gas production from new wells drilled during 1991 and 1992 on the Company's leases in the Vernal area is classified as tight formation natural gas. (See 'Other Matters - Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). In 1993, natural gas sales from the Vernal area averaged 24 MMcf per day compared with approximately 29 MMcf per day maximum deliverability, both net to the Company. Production is from the Green River and Wasatch formations located at depths between 4,500-8,000 feet. The Company has an average working interest of approximately 60%. The Company drilled 14 wells in the Vernal area in 1993 and expects to maintain a comparable drilling program during 1994. CANADA. The Company is engaged in the exploration for and the development and production of natural gas and crude oil and the operation of natural gas processing plants in western Canada, principally in the provinces of Alberta, Saskatchewan, and Manitoba. The Company conducts operations from offices in Calgary. Effective December 31, 1992, the Company consummated the acquisition of a natural gas property located in the Sandhills field in Saskatchewan. The property was further developed in 1993 through the drilling of 150 wells resulting in deliverability net to the Company from the Sandhills property of approximately 36 MMcf per day at December 31, 1993. Maximum Canadian natural gas deliverability net to the Company at December 31, 1993 was approximately 76 MMcf per day, and the Company held approximately 324,000 net undeveloped acres in Canada. The Company expects to maintain an active drilling program in Canada during 1994. TRINIDAD. In November 1992, the Company was awarded a 95% working interest concession in the South East Coast Consortium Block offshore Trinidad, previously held by three government-owned energy companies. Three undeveloped fields containing crude oil and natural gas rich with condensate are scheduled for development over the next three to five years. Existing surplus processing and transportation capacity at the Pelican Field facilities owned and operated by Trinidadian companies is being used to process and transport the production. Natural gas is being sold into the local market under a take-or-pay agreement with the National Gas Company of Trinidad and Tobago. At December 31, 1993, maximum natural gas deliverability net to the Company was approximately 40 MMcf per day and the Company held approximately 74,000 net undeveloped acres in Trinidad. As a result of continued development activities, natural gas deliveries were averaging approximately 60 MMcf per day and condensate deliveries were averaging approximately 3.3 MBbl per day net to the Company as of mid-March 1994. The Company expects to maintain an active development drilling program in this area in 1994. OTHER INTERNATIONAL. The Company continues to pursue selected other conventional natural gas and crude oil opportunities outside North America. In 1993, two unsuccessful wells were drilled in Malaysia and one in the United Kingdom North Sea area. During 1994, the Company will pursue other exploitation opportunities in countries where indigenous natural gas reserves have been identified, particularly where synergies in natural gas transportation, processing and power cogeneration can be optimized with other Enron Corp. affiliated companies. The Company currently is actively involved in an effort to obtain joint venture concessions involving two oil fields (Panna and Mukta) and one natural gas field (Tapti) offshore India in the Bombay High area. Resolution is anticipated by mid-1994. In 1993, the Company continued expansion of its international opportunity portfolio in the coalbed methane recovery arena. In September 1992, the Company entered into an operating agreement under which it is serving as operator with another partner in a venture in the Lorraine Basin in France and under which it exercised, in March 1994, an option to acquire a 50% working interest in the concession. In addition, a 100% working interest concession has been obtained in the Galilee Basin in Queensland, Australia. Protocols have also been signed and joint venture agreements are in the government approval process in both Russia and Kazakhstan; joint feasibility studies are underway in China; and, several other high potential countries are under active investigation. 3 MARKETING WELLHEAD MARKETING. The Company's wellhead natural gas production is currently being sold on the spot market and under long-term natural gas contracts at market responsive prices. In many instances, the long-term contract prices closely approximate the prices received for natural gas being sold on the spot market. Approximately one-half of the Company's wellhead natural gas production is currently being sold to pipeline and marketing subsidiaries of Enron Corp. Substantially all of the Company's wellhead crude oil and condensate is sold under short-term contracts at market responsive prices. OTHER MARKETING. Enron Oil & Gas Marketing, Inc. ('EOGM'), a wholly-owned subsidiary of the Company, is a marketing company engaging in various marketing activities. Both the Company and EOGM contract to provide, under long-term agreements, natural gas to various purchasers and then aggregate the necessary supplies for the sales with purchases from various sources including third-party producers, marketing companies, pipelines or from the Company's own production. In addition, EOGM has purchased and constructed several small gathering systems in order to facilitate its entry into the gathering business on a limited basis. EOGM anticipates providing gathering services when such activity will enhance its capability as an aggregator and marketer. Both EOGM and the Company utilize other short and long-term hedging mechanisms including sales and purchases in the futures market and price swap agreements. These marketing activities have provided an effective balance in managing the Company's exposure to commodity price risks in the energy market. In September 1992, the Company sold a volumetric production payment for $326.8 million to a limited partnership of which an Enron Corp. affiliated company is general partner with a 1% interest. Under the terms of the production payment agreements, the Company conveyed a real property interest of approximately 124 billion cubic feet equivalent ('Bcfe') (136 trillion British thermal units) of natural gas and other hydrocarbons in the Big Piney area of Wyoming. Effective October 1, 1993, the agreements were amended providing for the extension of the original term of the volumetric production payment through March 31, 1999 and including a revised schedule of daily quantities of hydrocarbons to be delivered which is approximately one-half of the original schedule. The revised schedule will total approximately 89.1 Bcfe (97.8 trillion British thermal units) versus approximately 87.9 Bcfe (96.4 trillion British thermal units) remaining to be delivered under the original agreement. Daily quantities of hydrocarbons no longer required to be delivered under the revised schedule during the period from October 1, 1993 through June 30, 1996 are available for sale by the Company. The Company retains responsibility for its working interest share of the cost of operations. The Company also entered into a separate agreement with the same limited partnership whereby it has agreed to exchange volumes owned by the Company in the Midcontinent area and the Texas Gulf Coast area for equivalent volumes produced and owned by the limited partnership in the Big Piney area. The costs incurred, if any, to effect redeliveries pursuant to such exchange are borne by the Company. The Company also has contracted to supply natural gas to a Texas City, Texas cogeneration facility which is owned by Cogenron Inc. Cogenron Inc. is 50% owned by Enron Corp. The primary contract provides for the sale of natural gas under a fixed schedule of prices substantially above current spot market prices. Current deliveries of approximately 45 MMcf of natural gas per day are being supplied primarily by purchases at market responsive prices under a long-term agreement with an Enron Corp. subsidiary. The Company has also entered into a price swap agreement with a third party that has the effect of converting the prices under this contract to a fixed schedule of prices. The resulting prices under this combination of purchase and price swap agreements are substantially below the fixed schedule of prices in the primary sales contract. The arrangements are designed, as to the volumes involved, to provide the Company a fixed margin of profit under its agreement with Cogenron Inc. However, the Company's commitment to deliver volumes of natural gas in excess of the current delivery levels at the schedule of predetermined prices discussed above could be disadvantageous to the Company during any time spot market prices exceed the applicable contract prices for natural gas. 4 WELLHEAD VOLUMES AND PRICES, AND LEASE AND WELL EXPENSES The following table sets forth certain information regarding the Company's wellhead volumes of and average prices for natural gas per thousand cubic feet ('Mcf'), crude oil and condensate, and natural gas liquids per barrel ('Bbl'), and average lease and well expenses per thousand cubic feet equivalent ('Mcfe' - natural gas equivalents are determined using the ratio of 6.0 Mcf of natural gas to 1.0 barrel of crude oil and condensate or natural gas liquids) delivered during each of the three years in the period ended December 31, 1993: YEAR ENDED DECEMBER 31, 1993 1992 1991 VOLUMES (PER DAY) Natural Gas (MMcf) United States---------------- 648.6(1) 533.6(1) 465.8 Canada----------------------- 58.4 30.0 24.8 Trinidad--------------------- 2.3 - - Total---------------------- 709.3(1) 563.6(1) 490.6 Crude Oil and Condensate (MBbl) United States---------------- 6.6 6.3 5.9 Canada----------------------- 2.2 2.2 2.3 Trinidad--------------------- .1 - - Total---------------------- 8.9 8.5 8.2 Natural Gas Liquids (MBbl) United States---------------- .2 .3 .3 Canada----------------------- .4 .4 .3 Trinidad--------------------- - - - Total---------------------- .6 .7 .6 AVERAGE PRICES Natural Gas ($/Mcf) United States---------------- $ 1.97(2) $ 1.61(2) $ 1.38 Canada----------------------- 1.34 1.18 1.32 Trinidad--------------------- .89 - - Composite------------------ 1.92(2) 1.58(2) 1.37 Crude Oil and Condensate ($/Bbl) United States---------------- $ 16.96 $ 18.29 $ 19.24 Canada----------------------- 14.63 16.80 17.58 Trinidad--------------------- 14.36 - - Composite------------------ 16.37 17.90 18.78 Natural Gas Liquids ($/Bbl) United States---------------- $ 13.85 $ 11.56 $ 10.79 Canada----------------------- 9.46 10.05 12.48 Trinidad--------------------- - - - Composite------------------ 11.12 10.69 11.64 LEASE AND WELL EXPENSES ($/MCFE) United States---------------- $ .18 $ .20 $ .23 Canada----------------------- .48 .50 .57 Trinidad--------------------- 1.46 - - Composite------------------ .21 .22 .25 (1) Includes 81.0 MMcf per day in 1993 and 27.6 MMcf per day in 1992 delivered under the terms of a volumetric production payment agreement effective October 1, 1992, as amended. (2) Includes an average equivalent wellhead value of $1.57 per Mcf in 1993 and $1.70 per Mcf in 1992 for the volumes described in note (1), net of transportation costs. 5 OTHER NATURAL GAS MARKETING VOLUMES AND PRICES The following table sets forth certain information regarding the Company's volumes of natural gas delivered under other marketing and volumetric production payment arrangements, and resulting average of sales prices and per unit amortization of deferred revenues along with associated costs during each of the three years in the period ended December 31, 1993. (See 'Marketing' for a discussion of other natural gas marketing arrangements and agreements). YEAR ENDED DECEMBER 31, 1993 1992 1991 Volumes (MMcf per day)--------------- 293.4(1) 254.9(1) 237.2 Average Gross Revenue ($/Mcf)-------- $ 2.57(2) $ 2.62(2) $ 2.63 Associated Costs ($/Mcf)(4)---------- 2.32(3) 1.99(3) 1.75 Margin ($/Mcf)----------------------- $ 0.25 $ 0.63 $ 0.88 (1) Includes 81.0 MMcf per day in 1993 and 27.6 MMcf per day in 1992 delivered under the terms of volumetric production payment and exchange agreements effective October 1, 1992, as amended. (2) Includes per unit deferred revenue amortization for the volumes detailed in note (1) at an equivalent of $2.50 per Mcf ($2.40 per million British thermal units) in 1993 and $2.51 per Mcf ($2.40 per million British thermal units) in 1992. (3) Includes an average value of $2.20 per Mcf in 1993 and $2.37 per Mcf in 1992, including average equivalent wellhead value, any applicable transportation costs and exchange differentials, for the volumes detailed in note (1). (4) Including transportation and exchange differentials. COMPETITION The Company actively competes for reserve acquisitions and exploration leases, licenses and concessions, frequently against companies with substantially larger financial and other resources. To the extent the Company's exploration budget is lower than that of certain of its competitors, the Company may be disadvantaged in effectively competing for certain reserves, leases, licenses and concessions. Competitive factors include price, contract terms, and quality of service, including pipeline connection times and distribution efficiencies. In addition, the Company faces competition from other producers and suppliers, including competition from Canadian natural gas. REGULATION DOMESTIC REGULATION OF NATURAL GAS AND CRUDE OIL PRODUCTION. Natural gas and crude oil production operations are subject to various types of regulation, including regulation in the United States by state and federal agencies. Domestic legislation affecting the oil and gas industry is under constant review for amendment or expansion. Also, numerous departments and agencies, both federal and state, are authorized by statute to issue and have issued rules and regulations which, among other things, require permits for the drilling of wells, regulate the spacing of wells, prevent the waste of natural gas and crude oil resources through proration, require drilling bonds and regulate environmental and safety matters. The regulatory burden on the oil and gas industry increases its cost of doing business and, consequently, affects its profitability. A substantial portion of the Company's oil and gas leases in the Big Piney area and in the Gulf of Mexico, as well as some in other areas, are granted by the federal government and administered by the Bureau of Land Management (the 'BLM') and the Minerals Management Service (the 'MMS') federal agencies. Operations conducted by the Company on federal oil and gas leases must comply with numerous statutory and regulatory restrictions. Certain operations must be conducted pursuant to appropriate permits issued by the BLM and the MMS. 6 Sales of crude oil, condensate and natural gas liquids by the Company are made at unregulated market prices. The transportation and sale for resale of natural gas in interstate commerce are regulated pursuant to the Natural Gas Act of 1938 (the 'NGA') and the Natural Gas Policy Act of 1978 (the 'NGPA'). These statutes are administered by the Federal Energy Regulatory Commission (the 'FERC'). Effective January 1, 1993, the Natural Gas Wellhead Decontrol Act of 1989 deregulated natural gas prices for all 'first sales' of natural gas, which includes all sales by the Company of its own production. Consequently, sales of the Company's natural gas currently may be made at market prices, subject to applicable contract provisions. Regulation of natural gas importation is administered primarily by the Department of Energy's Office of Fossil Energy (the 'DOE/FE'), pursuant to the NGA. The NGA provides that any party seeking to import natural gas must first seek DOE/FE authorization, which authorization may be granted, modified or denied in accordance with the public interest. The Energy Policy Act of 1992 amended the NGA's public interest standard with respect to imports from and exports to certain countries, such as Canada, to deem imports from and exports to such countries to be in the public interest, and require such import/export applications to be granted without delay. In addition, the Energy Policy Act amended the NGPA to treat natural gas imported from Canada as 'first sales' of natural gas under Section 3 of the NGPA, thus allowing such imported natural gas to be sold for resale without certificate authorization from the FERC. Additionally, the National Energy Board of Canada has dramatically revised its natural gas export policies to permit large volumes of Canadian natural gas to compete with natural gas produced in the U.S. for the U.S. spot market. Additional natural gas pipeline capacity from Canada to the U.S. has been built and other such construction proposals are pending approval. While the impact on the Company of this change is uncertain, it is possible that it will increase competition in the markets in which the Company sells natural gas. For example, Canadian natural gas competes directly with natural gas produced from the Company's Big Piney area for customers located in the Pacific Northwest region of the United States. Since 1985, the FERC has endeavored to make natural gas transportation more accessible to gas buyers and sellers on an open and non-discriminatory basis. These efforts have significantly altered the marketing and pricing of natural gas. The FERC's latest action in this area is Order No. 636, issued in April 1992, which mandates a fundamental restructuring of interstate pipeline sales and transportation services. Order No. 636 requires interstate natural gas pipelines to 'unbundle' or segregate the sales, transportation, storage, and other components of their existing city-gate sales service, and to separately state the rates for each unbundled service. Under Order No. 636, unbundled pipeline sales can be made only in the production areas. Order No. 636 also requires interstate pipelines to assign capacity rights they have on upstream pipelines to such pipelines' former sales customers and provides for the recovery by interstate pipelines of costs associated with the transition from providing bundled sales services to providing unbundled transportation and storage services. The purpose of Order No. 636 is to further enhance competition in the natural gas industry by assuring the comparability of pipeline sales service and services offered by a pipelines' competitors. Various aspects of Order No. 636 were challenged, including alleged shifts of costs between pipeline customer groups and the continuing reliability of unbundled services. In two subsequent orders on rehearing of Order No. 636, namely Order Nos. 636-A and 636-B, the FERC modified the original order in response to these and other concerns. As of early February 1994, the FERC had issued final orders accepting most pipelines' Order No. 636 compliance filings. Numerous parties have filed petitions for court review of Order Nos. 636, 636-A and 636-B, as well as orders in individual pipeline restructuring proceedings. Upon such judicial review, these orders may be reversed in whole or in part. Order No. 636 does not directly regulate the Company's activities, but has had and will have an indirect effect because of its broad scope. With Order No. 636 only partially implemented and subject to court review, it is difficult to predict with precision its effects. In many instances, 7 however, Order No. 636 has substantially reduced or brought to an end interstate pipelines' traditional role as wholesalers of natural gas in favor of providing only storage and transportation services. Order No. 636 has also created substantial uncertainty with respect to the marketing and transportation of natural gas. In spite of this uncertainty, Order No. 636 may enhance the Company's ability to market and transport its natural gas production. In December 1992, the FERC issued Order No. 547, governing the issuance of blanket marketer sales certificates to all natural gas sellers other than interstate pipelines. The order eliminates the need for natural gas producers and marketers to seek specific authorization under Section 7 of the NGA from the FERC to make sales of natural gas, such as imported natural gas and natural gas purchased from interstate pipelines. Instead, effective January 7, 1993, these natural gas sellers, by operation of the order, will be issued blanket certificates of public convenience and necessity allowing them to make jurisdictional natural gas sales for resale at negotiated rates without seeking specific FERC authorization. For marketers affiliated with interstate pipelines, Order No. 547 becomes effective for sales involving each affiliated pipeline as that pipeline complies with Order No. 636. The FERC intends Order No. 547, in tandem with Order No. 636, to foster a competitive market for natural gas by giving natural gas purchasers access to multiple supply sources at market-driven prices. The Company, as a natural gas producer, is covered by Order No. 547 and stands to benefit from the opportunity to market natural gas more freely under the blanket certificate as well as from the potential improvement in access to multiple natural gas purchasers. In December 1993, the FERC issued Order No. 497-E, which modified in some respects the standards of conduct, record keeping and reporting requirements and other measures that govern relationships between interstate pipelines and their marketing affiliates. Order No. 497-E narrowed the contemporaneous disclosure standard of conduct and the reporting requirements, while at the same time possibly expanding the class of pipeline and marketing affiliate employees to whom the standards of conduct apply. Order No. 497-E also extended until June 1994 the sunset date of the reporting requirements. The FERC simultaneously issued a notice of proposed rulemaking to revise these reporting requirements, which would establish new rules to go into effect before the June 1994 sunset date. Order No. 497 does not directly regulate the Company's activities, although a substantial portion of the Company's natural gas production is sold to or transported by interstate pipeline affiliates which are subject to the Order. The Company's activities may therefore be indirectly affected by these regulations. The Company owns, directly or indirectly, certain natural gas pipelines that it believes meet the traditional tests the FERC has used to establish a pipeline's status as a gatherer not subject to FERC jurisdiction under the NGA. State regulation of gathering facilities generally includes various safety, environmental, and in some circumstances, non-discriminatory take requirements, but does not generally entail rate regulation. Natural gas gathering may receive greater regulatory scrutiny at both the state and federal levels as the pipeline restructuring under Order No. 636 is implemented. For example, the State of Oklahoma recently enacted a prohibition against discriminatory gathering rates. In certain recent cases, the FERC has asserted ancillary NGA jurisdiction over gathering activities of interstate pipelines and their affiliates. In addition, the FERC recently convened a conference to consider issues relating to gathering services performed by interstate pipelines or their affiliates. The FERC intends to use information obtained to reevaluate the appropriateness of its traditional gathering criteria in light of Order No. 636 and to establish consistent policies for gathering rates and services for both interstate pipelines and their affiliates. It is not possible at this time to predict the outcome of this proceeding although it could ultimately affect access to and gathering rates for interstate gathering services. The Company's gathering operations could be adversely affected should they be subject in the future to the application of state or federal regulation of rates and services. The Company cannot predict the effect that any of the aforementioned orders or the challenges to such orders will ultimately have on the Company's operations. Additional proposals and proceedings that might affect the natural gas industry are pending before Congress, the FERC and the courts. 8 The Company cannot predict when or whether any such proposals or proceedings may become effective. It should also be noted that the natural gas industry historically has been very heavily regulated; therefore, there is no assurance that the less regulated approach currently being pursued by the FERC will continue indefinitely. Thus, the Company cannot predict the ultimate outcome or durability of the unbundled regulatory regime mandated by Order No. 636. ENVIRONMENTAL REGULATION. Various federal, state and local laws and regulations covering the discharge of materials into the environment, or otherwise relating to the protection of the environment, may affect the Company's operations and costs as a result of their effect on natural gas and crude oil exploration, development and production operations. It is not anticipated that the Company will be required in the near future to expend amounts that are material in relation to its total exploration and development expenditure program by reason of environmental laws and regulations, but inasmuch as such laws and regulations are frequently changed, the Company is unable to predict the ultimate cost of compliance. The Company has been named as a potentially responsible party in one Comprehensive Environmental Response Compensation and Liability Act proceeding. However, management does not believe that any potential assessment resulting from such proceeding will have a materially adverse effect on the financial condition or results of operations of the Company. CANADIAN REGULATION. In Canada, the petroleum industry operates under Federal, provincial and municipal legislation and regulations governing land tenure, royalties, production rates, pricing, environmental protection, exports and other matters. The price of natural gas and crude oil in Canada has been deregulated and is now determined by market conditions and negotiations between buyers and sellers. Various matters relating to the transportation and export of natural gas continue to be subject to regulation by both provincial and Federal agencies; however, the North American Free Trade Agreement has reduced the risk of altering cross-border commercial transactions. Canadian governmental regulations may have a material effect on the economic parameters for engaging in oil and gas activities in Canada and may have a material effect on the advisability of investments in Canadian oil and gas drilling activities. The Company is monitoring political, regulatory and economic developments in Canada. RELATIONSHIP BETWEEN THE COMPANY AND ENRON CORP. OWNERSHIP OF COMMON STOCK. Enron Corp. owns 80% of the outstanding shares of common stock of the Company and, through its ability to elect all directors of the Company, has the ability to control all matters relating to the management of the Company, including any determination with respect to acquisition or disposition of Company assets, future issuance of common stock or other securities of the Company and any dividends payable on the common stock. Enron Corp. also has the ability to control the Company's exploration, development, acquisition and operating expenditure plans. If Enron Corp. should sell a substantial amount of the common stock of the Company that it owns, such action could adversely affect the prevailing market price for the common stock and could impair the Company's ability to raise capital through the sale of its equity securities. In addition, a sale by Enron Corp. of any common stock owned by Enron Corp. would cause Enron Corp.'s ownership interest in the Company to fall below 80% with the result that (i) the Company would cease to be included in the consolidated federal income tax return filed by Enron Corp. and (ii) the tax allocation agreement between the Company and Enron Corp. described below would terminate. The Company has granted certain registration rights to Enron Corp. with respect to the common stock owned by Enron Corp. (See 'Contractual Arrangements' below). There is no agreement between Enron Corp. and any other party, including the Company, that would prevent Enron Corp. from acquiring additional shares of common stock of the Company. 9 CONTRACTUAL ARRANGEMENTS. The Company entered into a Services Agreement (the 'Services Agreement') with Enron Corp. effective January 1989, pursuant to which Enron Corp. provided various services, such as maintenance of certain employee benefit plans, provision of telecommunications and computer services, lease of office space and the provision of purchasing and operating services and certain other corporate staff and support services. Such services historically have been supplied to the Company by Enron Corp., and the Services Agreement provided for the further delivery of such services substantially identical in nature and quality to those services previously provided. The Company agreed to a fixed rate for the rental of office space and to reimburse Enron Corp. for all other direct costs incurred in rendering services to the Company under the contract and to pay Enron Corp. for allocated indirect costs incurred in rendering such services up to an annual maximum of $8 million, such cap to be increased for inflation and certain changes in the Company's allocation bases with the increase limited to a maximum of 10% per year. The Services Agreement was for an initial term of five years through December 1993. Effective January 1, 1994, the Company and Enron Corp. entered into a new services agreement (the 'New Services Agreement') pursuant to which Enron Corp. will, among other things, provide for the Company similar services substantially identical in nature and quality to those provided under terms of the previous agreement. The Company has agreed to pay and to reimburse Enron Corp. on bases essentially consistent with those included in the previous agreement, except that allocated indirect costs are subject to an annual maximum of $6.7 million for the year 1994 with any increase in such maximum for subsequent years not to exceed 7.5% per year. The New Services Agreement is for an initial term of five years through December 1998 and will continue thereafter until terminated by either party. The Company is included in the consolidated federal income tax return filed by Enron Corp. as the common parent for itself and its subsidiaries and affiliated companies, excluding any foreign subsidiaries. Consistent therewith and pursuant to a Tax Allocation Agreement (the 'Tax Agreement') between the Company, the Company's subsidiaries and Enron Corp., either Enron Corp. will pay to the Company and each subsidiary an amount equal to the tax benefit realized in the Enron Corp. consolidated federal income tax return resulting from the utilization of the Company's or the subsidiary's net operating losses and/or tax credits, or the Company and each subsidiary will pay to Enron Corp. an amount equal to the federal income tax computed on its separate taxable income less the tax benefits associated with any net operating losses and/or tax credits generated by the Company or the subsidiary which are utilized in the Enron Corp. consolidated return. Enron Corp. will pay the Company and each subsidiary for the tax benefits associated with their net operating losses and tax credits utilized in the Enron Corp. consolidated return, provided that a tax benefit was realized except as discussed in the following paragraph, even if such benefits could not have been used by the Company or the subsidiary on a separately filed tax return. In 1991, the Company and Enron Corp. modified the Tax Agreement to provide that, through 1992, the Company will realize the benefit of certain tight gas sand federal income tax credits available to the Company on a stand alone basis. The Company has also entered into an agreement with Enron Corp. providing for the Company to be paid for all realizable benefits associated with tight gas sand federal income tax credits concurrent with tax reporting and settlement for the periods in which they are generated. (See 'Other Matters Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption'). The Tax Agreement applies to the Company and each of its subsidiaries for all years in which the Company or any of its subsidiaries are or were included in the Enron Corp. consolidated return. To the extent a state or other taxing jurisdiction requires or permits a consolidated, combined, or unitary tax return to be filed and such return includes the Company or any of its subsidiaries, the principles expressed with respect to consolidated federal income tax allocation shall apply. Pursuant to the terms of a Stock Restriction and Registration Agreement with Enron Corp., the Company has agreed that upon the request of Enron Corp. (or certain assignees), the Company will register under the Securities Act of 1933 and applicable state securities laws the sale of the Company 10 common stock owned by Enron Corp. which Enron Corp. has requested to be registered. The Company's obligation is subject to certain limitations relating to a minimum amount of common stock required for registration, the timing of registration and other similar matters. The Company is obligated to pay all expenses incidental to such registration, excluding underwriters' discounts and commissions and certain legal fees and expenses. CONFLICTS OF INTEREST. The nature of the respective businesses of the Company and Enron Corp. and its affiliates is such as to potentially give rise to conflicts of interest between the two companies. Conflicts could arise, for example, with respect to transactions involving purchases, sales and transportation of natural gas and other business dealings between the Company and Enron Corp. and its affiliates, potential acquisitions of businesses or oil and gas properties, the issuance of additional shares of voting securities, the election of directors or the payment of dividends by the Company. Enron Corp. has advised the Company that it does not currently intend to engage in the exploration for and/or development and production of natural gas and crude oil except through its ownership of common stock of the Company. However, circumstances may arise that would cause Enron Corp. to engage in the exploration for and/or development and production of natural gas and crude oil in competition with the Company. For example, opportunities might arise which would require financial resources greater than those available to the Company or which are located in areas or countries in which the Company does not intend to operate. Also, Enron Corp. might acquire a competing oil and gas business as part of a larger acquisition. In addition, as part of Enron Corp.'s strategy of securing supplies of natural gas, Enron Corp. may from time to time acquire producing properties, and thereafter engage in exploration, development and production activities with respect to such properties. Such acquisition, exploration, development and production activities may directly or indirectly compete with the Company's business. Thus, there can be no assurances that Enron Corp. will not engage in the natural gas and crude oil exploration, development and production business in competition with the Company. The Company and Enron Corp. and its affiliates have in the past entered into significant intercompany transactions and agreements incident to their respective businesses, and the Company and Enron Corp. and its affiliates may be expected to enter into material transactions and agreements from time to time in the future. Such transactions and agreements have related to, among other things, the purchase and sale of natural gas, the financing of exploration and development efforts by the Company, and the provision of certain corporate services. (See 'Marketing' and the Consolidated Financial Statements and notes thereto). The Company believes that its existing transactions and agreements with Enron Corp. and its affiliates have been at least as favorable to the Company as could be obtained from third parties, and the Company intends that the terms of any future transactions and agreements between the Company and Enron Corp. and its affiliates will be at least as favorable to the Company as could be obtained from third parties. OTHER MATTERS ENERGY PRICES. Since the Company is primarily a natural gas company, it is more significantly impacted by changes in natural gas prices than in the prices for crude oil, condensate and natural gas liquids. During recent periods, natural gas has been priced significantly below parity with crude oil, condensate and natural gas liquids based on the energy equivalency of, and differences in transportation and processing costs associated with, the respective products. This imbalance in parity has been primarily driven by, among other things, a supply of domestic natural gas volumes in excess of demand requirements. The Company is unable to predict when this supply imbalance may resolve due to the significant impacts of factors such as general economic conditions, weather and other international energy supplies over which the Company has no control. However, during the latter part of 1993, certain shifts in the pricing structure for natural gas and crude oil and condensate suggest that the significance of the lack of parity between natural gas and crude oil and condensate pricing may be beginning to lessen. 11 Natural gas prices have fluctuated, at times rather dramatically, during the last three years. These fluctuations have resulted in an overall increase in average wellhead natural gas prices realized by the Company of 15% from 1991 to 1992 and 22% from 1992 to 1993. Due to the many uncertainties associated with the world political environment, the availabilities of other world wide energy supplies and the relative competitive relationships of the various energy sources in the view of the consumers, the Company is unable to predict what changes may occur in natural gas prices in the future. Crude oil and condensate prices also have fluctuated, at times rather dramatically, during the last three years. These fluctuations have resulted in an overall decline in average wellhead crude and condensate prices realized by the Company of 5% from 1991 to 1992 and 9% from 1992 to 1993. Due to the many uncertainties associated with the world political environment, the availabilities of other world wide energy supplies and the relative competitive relationships of the various energy sources in the view of the consumers, the Company is unable to predict what changes may occur in crude oil and condensate prices in the future. TIGHT GAS SAND TAX CREDITS (SECTION 29) AND SEVERANCE TAX EXEMPTION. Federal tax law provides a tax credit for production of certain fuels produced from nonconventional sources (including natural gas produced from tight formations), subject to a number of limitations. Fuels qualifying for the credit must be produced from a well drilled or a facility placed in service before January 1, 1993, and must be sold before January 1, 2003. The credit, which is currently approximately $.52 per MMBtu of natural gas, is computed by reference to the price of crude oil, and is phased out as the price of crude oil exceeds $23.50 in 1980 dollars (adjusted for inflation) with complete phaseout if such price exceeds $29.50 in 1980 dollars (similarly adjusted). Under this formula, the commencement of phaseout would be triggered if the average price for crude oil rose above approximately $43 per barrel in current dollars. Significant benefits from the tax credit are accruing to the Company since a portion (and in some cases a substantial portion) of the Company's natural gas production from new wells drilled after November 5, 1990, and before January 1, 1993, on the Company's leases in several of the Company's significant producing areas qualify for this tax credit. Certain natural gas production from wells spudded or completed after May 24, 1989 and before September 1, 1996 in tight formations in Texas qualifies for a ten-year exemption, ending August 31, 2001, from Texas severance taxes, subject to certain limitations. OTHER. All of the Company's oil and gas activities are subject to the risks normally incident to the exploration for and development and production of natural gas and crude oil, including blowouts, cratering and fires, each of which could result in damage to life and property. Offshore operations are subject to usual marine perils, including hurricanes and other adverse weather conditions, and governmental regulations as well as interruption or termination by governmental authorities based on environmental and other considerations. In accordance with customary industry practices, insurance is maintained by the Company against some, but not all, of the risks. Losses and liabilities arising from such events could reduce revenues and increase costs to the Company to the extent not covered by insurance. The Company's overseas operations are subject to certain risks, including expropriation of assets, risks of increases in taxes and government royalties, renegotiation of contracts with foreign governments, political instability, payment delays, limits on allowable levels of production and current exchange and repatriation losses, as well as changes in laws and policies governing operations of overseas-based companies generally. 12 CURRENT EXECUTIVE OFFICERS OF THE REGISTRANT The current executive officers of the Company and their names and ages are as follows: NAME AGE POSITION Forrest E. Hoglund----------------- 60 Chairman of the Board, President and Chief Executive Officer; Director Joe Michael McKinney--------------- 54 President-International Operations Mark G. Papa----------------------- 47 President-North American Operations George E. Uthlaut------------------ 60 Senior Vice President-Operations Walter C. Wilson------------------- 51 Senior Vice President and Chief Financial Officer Ben B. Boyd------------------------ 52 Vice President and Controller Dennis M. Ulak--------------------- 40 Vice President and General Counsel Forrest E. Hoglund joined the Company as Chairman of the Board, Chief Executive Officer and Director in September 1987. Since May 1990, he has also served as President of the Company. Mr. Hoglund was a director of USX Corporation from February 1986 until September 1987. He joined Texas Oil & Gas Corp. ('TXO') in 1977 as president, was named Chief Operating Officer in 1979, Chief Executive Officer in 1982, and served TXO in those capacities until September 1987. Mr. Hoglund is also a director of Texas Commerce Bancshares, Inc. Joe Michael McKinney has been President-International Operations since February 1994 with responsibilities for all exploration, drilling, production and engineering activities for the Company's international ventures outside North America. Mr. McKinney joined Enron Exploration Company, a wholly-owned subsidiary of the Company, in December 1991 as Senior Vice President of Operations and was elected President and Chief Operating Officer of Enron Exploration Company in April 1993, a capacity in which he continues to serve. Prior to joining the Company, Mr. McKinney held operations management positions with Union Texas Petroleum Company, The Superior Oil Company and Exxon Company, USA. Mark G. Papa has been President-North American Operations since February 1994. From May 1986 through January 1994, Mr. Papa served as Senior Vice President-Operations. Mr. Papa joined Belco Petroleum Corporation, a predecessor of the Company, in 1981 as Division Production Coordinator and served as Senior Vice President-Drilling and Production, BelNorth Petroleum Corporation from May 1984 until May 1986. George E. Uthlaut has been Senior Vice President-Operations of the Company since November 1987. Mr. Uthlaut was previously employed by Exxon Corporation (and affiliates) for 29 years in a number of managerial and technical positions. His last position was Headquarters Operations Manager, Production Department, Exxon Company, USA. Walter C. Wilson has been Senior Vice President and Chief Financial Officer since May 1991. Mr. Wilson joined the Company in November 1987 as Vice President and Controller and was named Senior Vice President-Finance in October 1988. Prior to joining the Company Mr. Wilson held financial management positions with Exxon Company, USA for 16 years and The Superior Oil Company for 4 years. Ben B. Boyd has been Vice President and Controller since March 1991. Mr. Boyd joined the Company in March 1989 as Director of Accounting and was named Controller in May 1990. Prior to joining the Company, Mr. Boyd held financial management positions with DeNovo Oil & Gas, Inc., Scurlock Oil Company and Coopers & Lybrand. Dennis M. Ulak has been Vice President and General Counsel since March 1992. Mr. Ulak joined the Company in March 1987 as Senior Counsel and was named Assistant General Counsel in 13 August 1990. Prior to joining the Company, Mr. Ulak held various legal positions with Enron Corp. and Northern Natural Gas Company. ITEM 2. PROPERTIES OIL AND GAS EXPLORATION AND PRODUCTION PROPERTIES AND RESERVES RESERVE INFORMATION. For estimates of the Company's net proved and proved developed reserves of natural gas and liquids, including crude oil, condensate and natural gas liquids, see 'Supplemental Information to Consolidated Financial Statements.' There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the producer. The reserve data set forth in Supplemental Information to Consolidated Financial Statements represent only estimates. Reserve engineering is a subjective process of estimating underground accumulations of natural gas and liquids, including crude oil, condensate and natural gas liquids, that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the amount and quality of available data and of engineering and geological interpretation and judgment. As a result, estimates of different engineers normally vary. In addition, results of drilling, testing and production subsequent to the date of an estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities ultimately recovered. The meaningfulness of such estimates is highly dependent upon the accuracy of the assumptions upon which they were based. In general, the volume of production from oil and gas properties owned by the Company declines as reserves are depleted. Except to the extent the Company acquires additional properties containing proved reserves or conducts successful exploration and development activities, or both, the proved reserves of the Company will decline as reserves are produced. Volumes generated from future activities of the Company are therefore highly dependent upon the level of success in acquiring or finding additional reserves and the costs incurred in doing so. The Company's estimates of reserves filed with other federal agencies agree with the information set forth in Supplemental Information to Consolidated Financial Statements. 14 ACREAGE. The following table summarizes the Company's developed and undeveloped acreage at December 31, 1993. Excluded is acreage in which the Company's interest is limited to owned royalty, overriding royalty and other similar interests.
DEVELOPED UNDEVELOPED TOTAL GROSS NET GROSS NET GROSS NET United States Texas---------------------------- 411,223 306,705 252,543 229,348 663,766 536,053 Federal Offshore----------------- 199,053 96,719 280,701 253,233 479,754 349,952 Wyoming-------------------------- 164,836 109,528 211,414 159,676 376,250 269,204 Oklahoma------------------------- 102,495 58,724 45,640 39,136 148,135 97,860 Utah----------------------------- 58,540 47,032 32,772 27,435 91,312 74,467 New Mexico----------------------- 85,294 38,227 58,846 32,713 144,140 70,940 Kansas--------------------------- 4,148 4,048 27,402 26,029 31,550 30,077 California----------------------- 13,235 11,680 12,897 12,182 26,132 23,862 Colorado------------------------- 10,111 1,490 29,715 14,318 39,826 15,808 Mississippi---------------------- 1,940 1,852 7,876 7,178 9,816 9,030 Montana-------------------------- 1,301 1,169 8,250 6,437 9,551 7,606 North Dakota--------------------- 2,395 961 1,509 1,228 3,904 2,189 Louisiana------------------------ 946 797 1,445 712 2,391 1,509 Other---------------------------- 163 132 861 841 1,024 973 Total------------------------ 1,055,680 679,064 971,871 810,466 2,027,551 1,489,530 Canada Alberta-------------------------- 329,677 145,804 227,872 141,602 557,549 287,406 Saskatchewan--------------------- 140,929 121,791 179,818 179,818 320,747 301,609 Manitoba------------------------- 11,611 9,661 3,260 2,900 14,871 12,561 British Columbia----------------- 656 164 - - 656 164 Total Canada----------------- 482,873 277,420 410,950 324,320 893,823 601,740 Other International Australia------------------------ - - 9,600,000 9,600,000 9,600,000 9,600,000 Trinidad------------------------- 975 926 78,076 74,172 79,051 75,098 United Kingdom------------------- - - 199,855 49,964 199,855 49,964 Total Other International---- 975 926 9,877,931 9,724,136 9,878,906 9,725,062 Total-------------------- 1,539,528 957,410 11,260,752 10,858,922 12,800,280 11,816,332
PRODUCING WELL SUMMARY. The following table reflects the Company's ownership in gas wells in 316 fields and oil wells in 75 fields located in Texas, offshore Texas and Louisiana in the Gulf of Mexico, Oklahoma, New Mexico, Utah, Wyoming, California and various other states, Canada and Trinidad at December 31, 1993. Gross oil and gas wells include 229 with multiple completions. PRODUCTIVE WELLS GROSS NET Gas---------------------------------- 4,674 3,170 Oil---------------------------------- 884 527 Total---------------------------- 5,558 3,697 15 DRILLING AND ACQUISITION ACTIVITIES. During the years ended December 31, 1993, 1992 and 1991 the Company spent approximately $430.1, $395.7 and $254.8 million, respectively, for exploratory and development drilling and acquisition of leases and producing properties. The Company drilled, participated in the drilling of or acquired wells as set out in the table below for the periods indicated:
YEAR ENDED DECEMBER 31, 1993 1992 1991 GROSS NET GROSS NET GROSS NET Development Wells Completed Domestic Gas-------------------------- 352 279.00 484 399.06 193 165.25 Oil-------------------------- 45 19.01 19 10.80 6 3.89 Dry-------------------------- 59 46.83 64 56.12 29 21.43 Total---------------------- 456 344.84 567 465.98 228 190.57 International Gas-------------------------- 227 190.10 2 2.00 8 5.33 Oil-------------------------- 4 3.50 13 11.70 9 8.50 Dry-------------------------- 11 7.60 5 4.05 4 2.86 Total---------------------- 242 201.20 20 17.75 21 16.69 Total Development---------------- 698 546.04 587 483.73 249 207.26 Exploratory Wells Completed Domestic Gas-------------------------- 14 10.03 11 8.72 14 10.54 Oil-------------------------- 3 2.50 1 .40 1 1.00 Dry-------------------------- 32 22.08 16 13.42 13 10.38 Total---------------------- 49 34.61 28 22.54 28 21.92 International Gas-------------------------- 14 11.40 7 5.75 3 1.83 Oil-------------------------- 2 .90 4 3.69 1 .39 Dry-------------------------- 10 7.35 4 2.85 9 5.48 Total---------------------- 26 19.65 15 12.29 13 7.70 Total Exploratory---------------- 75 54.26 43 34.83 41 29.62 Total---------------------- 773 600.30 630 518.56 290 236.88 Wells in Progress at end of period----------------------------- 82 61.09 82 60.75 32 21.60 Total---------------------- 855 661.39 712 579.31 322 258.48 Wells Acquired Gas------------------------------ 44 26.44* 641 597.29* 100 70.10* Oil------------------------------ - 12.80* 28 25.80* 5 4.10* Total---------------------- 44 39.24 669 623.09 105 74.20 * Includes the acquisition of additional interests in certain wells in which the Company previously held an interest.
All of the Company's drilling activities are conducted on a contract basis with independent drilling contractors. The Company owns no drilling equipment. 16 ITEM 3. LEGAL PROCEEDINGS The Company and its subsidiaries and related companies are named defendants in numerous lawsuits and named parties in numerous governmental proceedings arising in the ordinary course of business. While the outcome of lawsuits or other proceedings against the Company cannot be predicted with certainty, management does not expect these matters to have a material adverse effect on the financial condition or results of operations of the Company. TransAmerican Natural Gas Corporation ('TransAmerican') has filed a petition against the Company and Enron Corp. alleging breach of contract, tortious interference with contract, misappropriation of trade secrets and violation of state antitrust laws. The petition, as amended, seeks actual damages of $100 million plus exemplary damages of $300 million. The Company has answered the petition and is actively defending the matter; in addition, the Company has filed counterclaims against TransAmerican and a third-party claim against its sole shareholder, John R. Stanley, alleging fraud, negligent misrepresentation and breach of state antitrust laws. Trial, originally set for February 7, 1994, is now set for September 12, 1994. Although no assurances can be given, the Company believes that the claims made by TransAmerican are totally without merit, that the ultimate resolution of the matter will not have a materially adverse effect on its financial condition or results of operations, and that such ultimate resolution could result in a recovery to the Company. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS There were no matters submitted to a vote of security holders during the fourth quarter of 1993. 17 PART II ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED SHAREHOLDER MATTERS The following table sets forth, for the periods indicated, the high and low sale prices per share for the common stock, as reported on the New York Stock Exchange Composite Tape, and the amount of cash dividends paid per share. PRICE RANGE CASH HIGH LOW DIVIDENDS 1991 First Quarter-------------------- 22.25 16.25 .05 Second Quarter------------------- 21.50 18.00 .05 Third Quarter-------------------- 24.63 17.63 .05 Fourth Quarter------------------- 25.13 19.25 .05 1992 First Quarter-------------------- 21.88 16.63 .05 Second Quarter------------------- 27.25 20.50 .05 Third Quarter-------------------- 35.88 25.38 .05 Fourth Quarter------------------- 34.38 27.50 .05 1993 First Quarter-------------------- 40.63 26.75 .06 Second Quarter------------------- 45.00 35.75 .06 Third Quarter-------------------- 53.63 39.75 .06 Fourth Quarter------------------- 54.00 34.13 .06 As of March 1, 1994, there were approximately 500 record holders of the Company's common stock, including individual participants in security position listings. There are an estimated 5,600 beneficial owners of the Company's common stock, including shares held in street name. Following the initial public offering and sale of its common stock in October 1989, the Company paid quarterly dividends of $0.05 per share beginning with an initial dividend paid in January 1990 with respect to the fourth quarter of 1989. Beginning in January 1993 with respect to the fourth quarter of 1992, the Company has paid quarterly dividends of $0.06 per share. The Company currently intends to continue to pay quarterly cash dividends on its outstanding shares of common stock. However, the determination of the amount of future cash dividends, if any, to be declared and paid will depend upon, among other things, the financial condition, funds from operations, level of exploration and development expenditure opportunities and future business prospects of the Company. 18 ITEM 6. SELECTED FINANCIAL DATA
YEAR ENDED DECEMBER 31, 1993 1992 1991 1990 1989 (RESTATED) (IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) STATEMENT OF INCOME (LOSS) DATA: Net operating revenues--------------- $ 567,702 $ 452,989 $ 387,605 $ 371,335 $ 289,416 Operating expenses Lease and well------------------- 59,344 49,406 49,922 43,806 39,889 Exploration---------------------- 36,921 33,278 31,470 35,031 23,988 Dry hole------------------------- 18,355 10,764 14,698 12,986 10,212 Impairment of unproved oil and gas properties----------------- 20,467 15,136 12,791 20,571 10,832 Depreciation, depletion and amortization------------------- 249,704 179,839 160,885 155,877 134,313 General and administrative------- 45,274 36,648 36,216 38,254 40,240 Taxes other than income---------- 35,396 28,346 18,222 22,966 23,760 Other---------------------------- - - - - (117) Total------------------------ 465,461 353,417 324,204 329,491 283,117 Operating income--------------------- 102,241 99,572 63,401 41,844 6,299 Other income------------------------- 19,953 2,561 11,768 29,649 18,065 Interest expense (net of interest capitalized)----------------------- 9,921 22,289 29,500 36,879 33,849 Income (loss) before income taxes---- 112,273 79,844 45,669 34,614 (9,485) Income tax benefit (1)--------------- (25,752)(2) (17,736) (2,247)(3) (10,854) (3,384) Net income (loss)-------------------- $ 138,025 $ 97,580 $ 47,916(3) $ 45,468 $ (6,101) Earnings (loss) per share of common stock------------------------------ $ 1.73 $ 1.26 $ .63(3) $ .60 $ (.09) Average number of common shares------ 79,983 77,267 75,900 75,900 66,838 AT DECEMBER 31, 1993 1992 1991 1990 1989 (RESTATED) (RESTATED) BALANCE SHEET DATA (IN THOUSANDS): Oil and gas properties - net--------- $ 1,546,045 $ 1,468,011 $ 1,339,666 $ 1,305,136 $ 1,249,657 Total assets------------------------- 1,811,162 1,731,012 1,455,608 1,417,939 1,365,819 Long-term debt Affiliate-------------------------- - - (4) 132,836 277,918 401,092(5) Other------------------------------ 153,000 150,000(4) 289,556 140,442 - Shareholders' equity----------------- 933,073 826,986(3)(4) 643,185(3) 610,042 582,321(5) (1) Includes benefits of approximately $65 million, $43 million and $17 million in 1993, 1992 and 1991, respectively, relating to tight gas sand federal income tax credits and $7 million and $25 million associated with the utilization of a net operating loss carryforward in 1991 and 1990, respectively. (2) Includes a benefit of $12 million from the reduction of the Company's accumulated deferred federal income tax liability partially offset by an approximate $7 million predominantly non-cash charge primarily to adjust the Company's accumulated deferred federal income tax liability for the increase in the corporate federal income tax rate from 34% to 35%. (3) The Company adopted Statement of Financial Accounting Standards (SFAS) No. 109 - 'Accounting for Income Taxes' effective January 1, 1993 and applied the provisions of the statement retroactively. As a result, the previously reported Income tax benefit and Net income (loss) for 1991 were restated to $2.2 million and $47.9 million ($.63 per share), respectively, from $9.2 million and $54.9 million ($.72 per share), respectively, a reduction to both of $7.0 19 million. The Net income (loss) for 1992 and 1993 were not affected by the restatement. The Company's consolidated balance sheets at December 31, 1992 and 1991 were also restated to reflect the increase to deferred income taxes payable of $7.0 million and the corresponding decrease to retained earnings of an equal amount. (4) In August 1992, the Company completed the sale of an additional 4,100,000 shares of common stock resulting in aggregate net proceeds to the Company of approximately $112 million used primarily to repay long-term debt. In September 1992, the Company completed the sale of a volumetric production payment, resulting in net proceeds of approximately $327 million used to repay long-term debt and for other general corporate purposes. (5) The Company completed an initial public offering of 11,500,000 shares of common stock in October 1989, resulting in aggregate net proceeds to the Company of approximately $202 million which were used to repay advances from affiliates.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS The following review of operations for each of the three years in the period ended December 31, 1993 should be read in conjunction with the consolidated financial statements of the Company and notes thereto beginning with page F-1. RESULTS OF OPERATIONS NET OPERATING REVENUES. Volume and price statistics for the specified years were as follows: YEAR ENDED DECEMBER 31, 1993 1992 1991 Wellhead Volumes Natural Gas (MMcf per day)------- 709.3(1) 563.6(1) 490.6 Crude Oil and Condensate (MBbl per day)----------------------- 8.9 8.5 8.2 Natural Gas Liquids (MBbl per day)--------------------------- 0.6 0.7 0.6 Wellhead Average Prices Natural Gas ($/Mcf)-------------- $ 1.92(2) $ 1.58(2) $ 1.37 Crude Oil and Condensate ($/Bbl)------------------------ 16.37 17.90 18.78 Natural Gas Liquids ($/Bbl)------ 11.12 10.69 11.64 Other Natural Gas Marketing Volumes (MMcf per day)----------- 293.4(1) 254.9(1) 237.2 Average Gross Revenue ($/Mcf)---- $ 2.57(3) $ 2.62(3) $ 2.63 Associated Costs ($/Mcf) (5)----- 2.32(4) 1.99(4) 1.75 Margin ($/Mcf)------------------- $ 0.25 $ 0.63 $ 0.88 (1) Includes 81.0 MMcf per day in 1993 and 27.6 MMcf per day in 1992 delivered under the terms of volumetric production payment and exchange agreements effective October 1, 1992, as amended. (2) Includes an average equivalent wellhead value of $1.57 per Mcf in 1993 and $1.70 per Mcf in 1992 for the volumes detailed in note (1), net of transportation costs. (3) Includes per unit deferred revenue amortization for the volumes detailed in note (1) at an equivalent of $2.50 per Mcf ($2.40 per million British thermal units) in 1993 and $2.51 per Mcf ($2.40 per million British thermal units) in 1992. (4) Includes an average value of $2.20 per Mcf in 1993 and $2.37 per Mcf in 1992, including average equivalent wellhead value, any applicable transportation costs and exchange differentials, for the volumes detailed in note (1). (5) Including transportation and exchange differentials. 20 During 1993, net operating revenues increased to $568 million, up $115 million as compared to 1992. Average wellhead natural gas volumes increased approximately 26% compared to 1992 primarily reflecting the effects of exploration and development activities relating to tight gas sand formations. Wellhead natural gas delivered volumes were curtailed less during portions of 1993 than for the comparable periods in 1992 due to the significant increases realized in wellhead natural gas prices in 1993. Average wellhead natural gas prices were up approximately 22% in 1993 over those received in 1992, adding approximately $87 million to net operating revenues. Increases in wellhead natural gas volumes in 1993 added $83 million to net operating revenues compared to 1992. Average wellhead crude oil and condensate prices in 1993 were down 9% compared to 1992, reducing net operating revenues by $5 million. Increases in wellhead crude oil and condensate volumes in 1993 added approximately $2 million to net operating revenues compared to 1992. Other marketing activities associated with sales and purchases of natural gas, natural gas price swap transactions, other commodity price hedging of natural gas and crude oil and condensate prices utilizing futures market transactions, and margins relating to the volumetric production payment added $8 million to net operating revenues during 1993. This decrease of $54 million from 1992 primarily results from shrinking margins associated with sales under long-term fixed price contracts and amortization of volumetric production payment deferred revenue due to increases in market responsive natural gas prices associated with volumes supplying these dispositions and losses on natural gas commodity price hedging activities utilizing NYMEX commodity market transactions. The average associated costs of natural gas marketing, price swap and volumetric production payment transactions, including, where appropriate, average wellhead value, transportation costs and exchange differentials, increased $.33 per Mcf. Related other natural gas marketing volumes increased 15%. The net reduction in benefits from these other marketing activities, a substantial portion of which serve as hedges of commodity price risks for a portion of wellhead deliveries, are more than offset by an increase in revenues associated with market responsive price increases for wellhead deliveries, as noted above. The $18 million hedging loss in 1993 associated with forward sales of natural gas using the NYMEX futures market reflects the effects of transactions sold over a period of time that turned out to be a continually increasing natural gas pricing period. If the stronger market responsive pricing environment continues, the incremental benefits realized by the Company in prior years from these other marketing activities will continue to be reduced. However, in such circumstances the Company will continue to realize more significant benefits from the improved pricing related to wellhead deliveries. (See Note 2 to Consolidated Financial Statements). During 1992, net operating revenues increased to $453 million, up $65 million as compared to 1991. Average wellhead natural gas volumes increased approximately 15% compared to 1991 primarily reflecting the effects of exploration and development activities relating to tight gas sand formations. Although exploration and development efforts resulted in deliverability increases in certain core areas, the potential earnings and cash flow benefits were mitigated by voluntary curtailments during 1992. Wellhead natural gas delivered volumes were voluntarily curtailed by as much as 25% of deliverability during portions of the year due to lower than acceptable prices. Average wellhead natural gas prices were up approximately 15% and average wellhead crude oil and condensate prices were down 5% compared to 1991. The increase in average wellhead natural gas price received by the Company increased net operating revenues by approximately $38 million. The increase in wellhead natural gas volumes added approximately $43 million to net operating revenues. Increases in wellhead crude oil and condensate delivered volumes added $2 million to net operating revenues. A decrease in the average wellhead crude oil and condensate price decreased net operating revenues by $3 million. 21 Other marketing activities associated with sales and purchases of natural gas, natural gas price swap transactions, natural gas and crude oil commodity price hedging utilizing futures market transactions and margins relating to the volumetric production payment added $63 million to net operating revenues during 1992, a decrease of $17 million from 1991. Other natural gas marketing volumes increased 7%. The average associated costs of supplying these commitments, including average equivalent wellhead value, transportation costs and exchange differentials, increased $.24 per Mcf. OPERATING EXPENSES. During 1993, total operating expenses of $465 million were $112 million higher than the $353 million incurred in 1992. Lease and well expenses increased approximately $10 million primarily due to expanded domestic and international operations. Exploration expenses increased approximately $4 million primarily due to increased exploration activities in North America. Dry hole expenses increased by almost $8 million and lease impairments were $5 million higher than in 1992. An unsuccessful domestic deep well added nearly $4 million to dry hole expenses and a related $3 million to lease impairments in 1993. Dry hole expenses also reflect the impact of increased drilling activity outside North America. Depreciation, depletion and amortization ('DD&A') expense increased $70 million to $250 million reflecting an increase in production volumes and an average DD&A rate increase from $.79 per Mcfe in 1992 to $.89 per Mcfe for 1993. The DD&A rate increase is primarily due, as expected, to factors associated with the tight gas sands drilling program which costs are being more than offset by benefits realized in the form of tight gas sand federal income tax credits and certain state severance tax exemptions. General and administrative expenses increased almost $9 million to $45 million primarily reflecting cost reductions included in 1992 related to changes associated with certain employee compensation plans and overall higher costs in 1993 due to an expansion of domestic and international operations. Taxes other than income increased $7 million primarily due to increased production volumes and revenues in 1993, partially offset by continuing benefits associated with certain state severance tax exemptions allowed on high cost natural gas sales and a $3 million reduction of state franchise taxes resulting from refunds of prior year payments received in 1993. Total per unit operating costs for lease and well expense, DD&A, general and administrative expense, interest expense, and taxes other than income increased $.03 per Mcfe, averaging $1.43 per Mcfe during 1993 compared to $1.40 per Mcfe for 1992. The total increase was associated with DD&A expense which was up $.10 per Mcfe as noted above being partially offset by a reduction of $.07 Mcfe in all other costs. During 1992, operating expenses increased $29 million to $353 million as compared to 1991. However, cost per Mcfe, including those associated with exploration expenditures, declined $.08 to $1.56 per Mcfe in 1992. Lease and well expenses remained essentially flat compared to 1991. However, lease and well expense per Mcfe declined $.03 per Mcfe to $.22 per Mcfe in 1992. Per unit operating cost reductions reflect the effects of a continuing focus on controlling operating costs in all areas of Company operations and benefits realized from the sale of properties which required higher maintenance costs along with increasing volumes which tend to reduce per unit impacts of costs that are more fixed in nature. Exploration expenses of $33 million increased $2 million over 1991 due to certain exploration activities in new international areas of interest. Dry hole expenses of $11 million decreased $4 million from 1991 due to decreased drilling activity in areas outside of North America partially mitigated by increased domestic drilling activities. Impairment of unproved oil and gas properties increased approximately $2 million to $15 million primarily reflecting certain costs associated with the decision to discontinue exploration activities in certain areas outside of North America, including Egypt, Indonesia and Syria in addition to reflecting the effects of accelerated relinquishments of certain domestic acreage holdings. DD&A expense increased $19 million to $180 million primarily reflecting increased production mitigated by a decline in the average DD&A rate from $.81 per Mcfe in 1991 to $.79 per Mcfe in 1992. The reduction in DD&A rates per Mcfe reflects the effects of a continuing focus on adding reserves with low finding costs along with the benefits of selling certain properties with higher than average cost bases. General and administrative 22 expenses increased $1 million to $37 million primarily reflecting the effects of expanded operations. Taxes other than income increased $10 million to $28 million due to increased production volumes and revenues in 1992, increases in certain ad valorem and state franchise taxes and earnings benefits associated with the refund of certain state natural gas severance taxes in 1991 resulting from overpayments in prior years. This increase was mitigated by Texas severance tax exemptions for certain high cost gas production during 1992. OTHER INCOME. Other income for 1993 of $20 million reflects an increase of $17 million from the $3 million recorded for 1992. Other income for 1993 includes $13 million in gains on sales of oil and gas properties, an increase of $7 million over 1992, $4 million in interest income associated with the investment of funds temporarily surplus to the Company (See Note 3 to Consolidated Financial Statements) and $4 million associated with settlements related to the termination of certain long-term natural gas contracts. Other income in 1992 was $3 million compared to $12 million in 1991. Other income in 1992 included $6 million in gains on sales of oil and gas properties compared to $15 million in 1991. INTEREST EXPENSE. Net interest expense decreased $12 million, or 55%, to $10 million in 1993 as compared to 1992 reflecting the repayment of a substantial portion of the Company's long-term debt in 1992 with proceeds from the sale of common stock in August 1992 and the sale of a volumetric production payment in September 1992. The estimated fair value of outstanding interest rate swap agreements at December 31, 1993 was a negative $3.3 million based upon termination values obtained from third parties. (See Note 12 to Consolidated Financial Statements). Net interest expense decreased $7 million, or 24%, to $22 million in 1992 as compared to 1991, reflecting a restructuring of debt in early 1991 and lower interest rates. Using interest rate swap agreements with third parties effective in January 1992, the Company fixed short-term borrowing costs for the year for the equivalent of $225 million of its floating rate obligations. In addition, two of the interest rate swap agreements in notional amounts totalling $75 million were for a two-year period extending through 1993. Effective January 1, 1993, Enron Corp. assumed the Company's remaining obligations under these swap agreements. INCOME TAXES. Income tax benefit in 1993 includes a benefit of approximately $65 million associated with tight gas sand federal income tax credit utilization, an approximate $7 million predominantly one-time non-cash charge recorded in the third quarter of 1993 primarily to adjust the Company's accumulated deferred federal income tax liability for the increase in the corporate federal income tax rate from 34% to 35% and a $12 million benefit from the reduction of the Company's accumulated deferred federal income tax liability resulting from a year end reevaluation of deferred tax liability requirements. The Company adopted SFAS No. 109 effective January 1, 1993 and applied the provisions of the statement retroactively. As a result, the previously reported income tax benefit and net income for 1991 were restated with a reduction to both of $7 million. Net income for 1992 and 1993 was not affected by the restatement. The Company's consolidated balance sheets at December 31, 1992 and 1991 were also restated to reflect the increase to deferred income taxes payable of $7 million and the corresponding decrease to retained earnings of an equal amount. Income tax benefit in 1992 includes a benefit of approximately $43 million associated with tight gas sand federal income tax credit utilization and $2.8 million primarily related to investment tax credit, tight gas sand federal income tax credit and percentage depletion utilization based on actual returns as filed and settlements on audit of tax returns of predecessor companies for the years 1984 through 1985. Income tax benefit in 1991 includes a benefit of approximately $17 million associated with tight gas sand federal income tax credit utilization and $10.5 million related to utilization of net operating loss carryforwards, foreign tax credit and settlements on audit of tax returns of predecessor companies for tax years 1980 through 1983. 23 CAPITAL RESOURCES AND LIQUIDITY CASH FLOW. The primary sources of cash for the Company during the three-year period ended December 31, 1993 included funds generated from operations, the sale of common stock, the sale of a volumetric production payment and proceeds from the sale of certain oil and gas properties. Primary cash outflows included funds used in operations, exploration and development expenditures, dividends, and the repayment of debt. Discretionary cash flow, a frequently used measure of performance for exploration and production companies, is generally derived by adjusting net income to eliminate the effects of depreciation, depletion and amortization, impairment of unproved oil and gas properties, deferred taxes, property sales net of tax, certain other miscellaneous non-cash amounts, except for amortization of deferred revenue, and exploration and dry hole expenses. In the case of the Company, the elimination of revenues associated with the amortization of deferred revenues created by the sale by the Company of a volumetric production payment is reflected in investing cash flows. The Company generated discretionary cash flow of approximately $487 million in 1993, $320 million in 1992 and $252 million in 1991. The 1993 amount includes $50 million associated with a federal income tax refund resulting from the settlement of an audit of federal income taxes paid in prior years. Net operating cash flows were approximately $480 million in 1993, $306 million in 1992 and $242 million in 1991. Increased 1993 net operating cash flows were primarily due to increased net operating revenues and a decrease in provision for current taxes resulting from both increased tight gas sand federal income tax credit utilization and proceeds from the receipt of a refund on settlement of an audit of federal income taxes paid in prior years. Increased 1992 net operating cash flows were primarily due to increased net operating revenues and an increase in current tax benefits as a result of tight gas sand federal income tax credit utilization. SALE OF CERTAIN PROPERTIES. In 1993, the Company received proceeds of $42 million from the sale of certain producing and non-producing oil and gas properties. Taxable gains resulting from these sales generated federal income taxes of $8 million, leaving net proceeds of $34 million. During 1992, the Company received proceeds of $33 million from the sale of certain producing and non-producing oil and gas properties. Taxable gains resulting from these sales generated federal income taxes of $8 million, leaving net proceeds of $25 million. In 1991, the Company received proceeds of $23 million from the sale of certain producing and non-producing oil and gas properties. Taxable gains resulting from these sales generated income taxes of $5 million, leaving net proceeds of $18 million. SALE OF COMMON STOCK. In August 1992, the Company completed the sale of 4.1 million shares of common stock resulting in aggregate net proceeds to the Company of approximately $112 million used primarily to repay long-term debt. Enron Corp. retained ownership of 80% of the Company. SALE OF VOLUMETRIC PRODUCTION PAYMENT. In September 1992, the Company sold a volumetric production payment for $326.8 million to a limited partnership. (See 'Business - Marketing - Other Marketing' and Note 4 to Consolidated Financial Statements). Under the terms of the production payment agreements, the Company conveyed a real property interest in approximately 124 bcfe (136 trillion British thermal units) of natural gas and other hydrocarbons in the Big Piney area of Wyoming to the purchaser. Effective October 1, 1993, the agreements were amended providing for the extension of the original term of the volumetric production payment through March 31, 1999 and including a revised schedule of daily quantities of hydrocarbons to be delivered which is approximately one-half of the original schedule. The revised schedule will total approximately 89.1 Bcfe (97.8 trillion British thermal units) versus approximately 87.9 Bcfe (96.4 trillion British thermal units) remaining to be delivered under the original agreement. Daily quantities of hydrocarbons no longer required to be delivered under the revised schedule during the period from October 1, 1993 through June 30, 1996 are available for sale by the Company. The Company retains responsibility for its working interest share of the cost of operations. A portion of the proceeds of the sale was used to repay a portion of the Company's long-term debt, with surplus funds advanced to Enron Corp. under a promissory note which facilitates the deposit of funds temporarily surplus to the Company. In 24 accordance with generally accepted accounting principles, the Company accounted for the proceeds received in the transaction as deferred revenue which is being amortized into revenue and income as natural gas and other hydrocarbons are produced and delivered to the purchaser during the term, as revised, of the volumetric production payment thereby matching those revenues with the depreciation of asset values which remained on the balance sheet following the sale and the operating expenses incurred for which the Company retained responsibility. The Company expects the above transaction, as amended, to have minimal impact on future earnings. However, cash made available by the sale of the volumetric production payment has provided considerable financial flexibility for the pursuit of investment alternatives. EXPLORATION AND DEVELOPMENT EXPENDITURES. The table below sets out components of actual exploration and development expenditures for the years ended December 31, 1993, 1992 and 1991, along with those budgeted for the year 1994. ACTUAL BUDGETED EXPENDITURE CATEGORY 1993 1992 1991 1994 (IN MILLIONS) Capital Drilling and Facilities--------- $ 331.0 $ 259.9 $ 149.3 $ 360.0 Leasehold Acquisitions---------- 29.1 23.0 12.6 20.0 Producing Property Acquisitions-------------------- 9.2 65.2 42.4 4.0 Capitalized Interest and Other------------------------- 13.7 14.3 7.4 10.0 Total----------------------- 383.0 362.4 211.7 394.0 Exploration Expenses---------------- 55.3 44.0 46.1 56.0 Total------------------------------- $ 438.3 $ 406.4 $ 257.8 $ 450.0 Exploration and development expenditures in 1993 increased to $438 million, an 8% increase, as compared to the $406 million expended in 1992. The increase was attributable to increased domestic drilling activity with reduced emphasis on development drilling expenditures associated with tight gas sand formations. The Company also implemented its first development program outside of North America. During 1992 and 1993, the Company had a platform set, production facilities in place and natural gas flowing from the Kiskadee field offshore the southeast coast of Trinidad. Exploration and development expenditures increased $149 million, or 58%, in 1992 compared to 1991. The increase was primarily attributable to increased development drilling expenditures associated with tight gas sand activities and the acquisition in December 1992 of approximately $40 million of producing properties in Canada. (See 'Business - Exploration and Production' for additional information detailing the specific geographic locations of the Company's drilling programs and 'Outlook' below for a discussion related to 1994 exploration and development expenditure plans). FINANCING. The Company's long-term debt-to-total-capital ratio was 14% and 15% as of December 31, 1993 and 1992, respectively. The Company has entered into an agreement with Enron Corp. pursuant to which the Company may borrow funds from Enron Corp. at a representative market rate of interest on a revolving basis. During 1993, there were no funds borrowed by the Company under this agreement. Under a promissory note effective January 1, 1993 at a fixed interest rate of 7%, the Company advances funds temporarily surplus to the Company to Enron Corp. for investment purposes. Daily outstanding balances of funds advanced to Enron Corp. under the note averaged $60 million during 1993 with a balance of $97 million outstanding at December 31, 1993. There were no balances outstanding at December 31, 1993 under a commercial paper program initiated in 1990. The proceeds from the commercial paper program outstanding from time to time are used to fund current transactions. During 1993, total long-term debt increased $3 million to $153 million as a result of $33 million of new borrowings related to certain international drilling 25 activities partially offset by $30 million classified as current maturities. (See Note 3 to the Consolidated Financial Statements). The estimated fair value of the Company's long-term debt, including current maturities of $30 million, at December 31, 1993 was $192 million based upon quoted market prices and, where such prices were not available, upon interest rates currently available to the Company at year end. (See Note 12 to the Consolidated Financial Statements). OUTLOOK. While the wellhead natural gas price environment was, on average, stronger during the year 1993, there continues to exist a good deal of uncertainty as to the direction of future natural gas price trends. However, recent experiences continue to suggest a possible converging of the overall supply/demand relationship reflecting, at least partially, the significantly reduced level of drilling activity during recent years. Management remains confident that continually increasing recognition of natural gas as a more environmentally friendly source of energy along with the availability of significant domestically sourced supplies will result in further increases in demand and a strengthening of the overall natural gas market over time. Being primarily a natural gas producer, the Company is more significantly impacted by changes in natural gas prices than by changes in crude oil and condensate prices. (See 'Business - Other Matters - Energy Prices'). Based on the portion of the Company's anticipated natural gas volumes for which prices have not, in effect, been hedged using the futures market and long-term marketing contracts, the Company's net income and cash flow sensitivity to changing natural gas prices is approximately $7 million for each $.10 per Mcf change in average wellhead natural gas prices. Using various commodity price hedging mechanisms, the Company has, in effect, locked in prices for an average of about two-thirds of its anticipated wellhead natural gas volumes for the year 1994. This level of hedging may change during the remainder of 1994 and will change in future years. Other factors representing positive impacts that are more certain continue to hold good potential for the Company in future periods. While the drilling qualification period for the tight gas sand federal income tax credit expired as of December 31, 1992, the Company has continued in 1993, and should continue in the future, to realize significant benefits associated with production from wells drilled during the qualifying period as it will be eligible for the federal income tax credit through the year 2002. However, all other factors remaining equal, the annual benefit, which was $65 million in 1993 and estimated to be approximately $40 million for 1994, is expected to continue to decline in future periods as production from the qualified wells declines. The drilling qualification period for a certain state severance tax exemption available on certain high cost natural gas revenues continues through the latter part of 1996. Consequently, new qualifying production will be added prospectively to that qualified at year end 1993. (See 'Business - Other Matters - Tight Gas Sand Tax Credit (Section 29) and Severance Tax Exemption'). Other natural gas marketing activities are also expected to continue to contribute meaningfully to financial results. However, the Company completed a fairly significant restructure of its other natural gas marketing portfolio during 1992 with the sale of a volumetric production payment of approximately 124 Bcfe (136 trillion British thermal units) for $326.8 million that was subsequently revised in 1993 (See 'Business - Marketing - Other Marketing' and Note 4 to Consolidated Financial Statements) and elimination of most delivery obligations under four long-term fixed price marketing contracts. The proceeds from the sale of the volumetric production payment added substantially to the financial flexibility of the Company supporting future development while the combined effect of all elements of the restructuring on net income has not been, and will not in the future be, significant. These factors are expected to contribute significantly to earnings, cash flow, and the ability of the Company to pursue the continuation of an active exploration, development and selective acquisition program. The Company will continue to focus development and certain exploration expenditures in its core and other major producing areas, and include limited but meaningful exploratory exposure in areas outside of North America. (See 'Business - Exploration and Production' for additional information detailing the specific geographic locations of the related drilling programs). Early-in-year activity will be managed within an annual expected expenditure level of approximately $450 million. This early-in-year planning will address the continuing uncertainty with regard to the future of the 26 natural gas price environment and will be structured to maintain the flexibility necessary under the Company strategy of funding exploration, development and acquisition activities primarily from available internally generated cash flow. Expenditure plans for 1994 will continue to be focused toward certain areas that were not addressed as actively in the recent past due to the increased emphasis on tight gas sand drilling opportunities during 1991 and 1992 that were completed in early 1993. The Company will also be continuing expenditures in new areas outside of North America, primarily for additional development operations in Trinidad, possible new development operations in other countries, such as those currently being pursued in India, and the continued evaluation of coalbed methane recovery potential in France, Australia, China and certain other countries. The level of exploration and development expenditures may vary in 1994 and will vary in future periods depending on energy market conditions and other related economic factors. Based upon existing economic and market conditions, the Company believes net operating cash flow and available financing alternatives in 1994 will be sufficient to fund its net investing cash requirements for the year. However, the Company has significant flexibility with respect to its financing alternatives and adjustment of its exploration and development expenditure plans as circumstances warrant. There are no material continuing commitments associated with expenditure plans. ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA The information required hereunder is included in this report as set forth in the 'Index to Financial Statements' on page F-1. ITEM 9. DISAGREEMENTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. PART III ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT The information required by this Item regarding directors is set forth in the Proxy Statement under the caption entitled 'Election of Directors', and is incorporated herein by reference. See list of 'Current Executive Officers of the Registrant' in Part I located elsewhere herein. There are no family relationships among the officers listed, and there are no arrangements or understandings pursuant to which any of them were elected as officers. Officers are appointed or elected annually by the Board of Directors at its first meeting following the Annual Meeting of Shareholders, each to hold office until the corresponding meeting of the Board in the next year or until a successor shall have been elected, appointed or shall have qualified. ITEM 11. EXECUTIVE COMPENSATION The information required by this Item is set forth in the Proxy Statement under the caption 'Compensation of Directors and Executive Officers', and is incorporated herein by reference. ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT The information required by this Item is set forth in the Proxy Statement under the captions 'Election of Directors' and 'Compensation of Directors and Executive Officers', and is incorporated herein by reference. ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS The information required by this Item is set forth in the Proxy Statement under the caption 'Compensation Committee Interlocks and Insider Participation', and is incorporated herein by reference. 27 PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K (A)(1) AND (2) FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES See 'Index to Financial Statements' set forth on page F-1. (A)(3) EXHIBITS See pages E-1 through E-3 for a listing of the exhibits. (B) REPORTS ON FORM 8-K No reports on Form 8-K were filed by the Company during the last quarter of 1993. 28 INDEX TO FINANCIAL STATEMENTS ENRON OIL & GAS COMPANY PAGE Consolidated Financial Statements: Management's Responsibility for Financial Reporting---- F-2 Report of Independent Public Accountants--------------- F-3 Consolidated Statements of Income for Each of the Three Years in the Period Ended December 31, 1993---- F-4 Consolidated Balance Sheets -December 31, 1993 and 1992--------------------------------------------- F-5 Consolidated Statements of Shareholders' Equity for Each of the Three Years in the Period Ended December 31, 1993------------------------------ F-6 Consolidated Statements of Cash Flows for Each of the Three Years in the Period Ended December 31, 1993------------------------------------ F-7 Notes to Consolidated Financial Statements------------- F-8 Supplemental Information to Consolidated Financial Statements----------------------------------------------- F-21 Financial Statement Schedules: Schedule V -Property, Plant and Equipment----------- S-1 Schedule VI -Accumulated Depreciation, Depletion and Amortization of Property, Plant and Equipment---- S-2 Schedule VIII -Valuation and Qualifying Accounts and Reserves----------------------------------------- S-3 Schedule X -Supplemental Income Statement Information------------------------------------------- S-4 Other financial statement schedules have been omitted because they are inapplicable or the information required therein is included elsewhere in the consolidated financial statements or notes thereto. F-1 MANAGEMENT'S RESPONSIBILITY FOR FINANCIAL REPORTING The following consolidated financial statements of Enron Oil & Gas Company and its subsidiaries were prepared by management which is responsible for their integrity, objectivity and fair presentation. The statements have been prepared in conformity with generally accepted accounting principles and accordingly include some amounts that are based on the best estimates and judgements of management. Arthur Andersen & Co., independent public accountants, was engaged to audit the consolidated financial statements of Enron Oil & Gas Company and its subsidiaries and issue a report thereon. In the conduct of the audit, Arthur Andersen & Co. was given unrestricted access to all financial records and related data including minutes of all meetings of shareholders, the Board of Directors and committees of the Board. Management believes that all representations made to Arthur Andersen & Co. during the audit were valid and appropriate. Their audits of the years presented included developing an overall understanding of the Company's accounting systems, procedures and internal controls, and conducting tests and other auditing procedures sufficient to support their opinion on the financial statements. The report of Arthur Andersen & Co. appears on the following page. The system of internal controls of Enron Oil & Gas Company and its subsidiaries is designed to provide reasonable assurance as to the reliability of financial records as represented in published interim and annual financial statements and for the protection of assets. This system includes, but is not limited to, written policies and guidelines including a published code for the conduct of business affairs, the careful selection and training of qualified personnel, and a documented organizational structure outlining the separation of responsibilities among management representatives and staff groups, augmented by a strong program of internal audit. The adequacy of financial controls of Enron Oil & Gas Company and its subsidiaries and the accounting principles employed in financial reporting by the Company are under the general oversight of the Audit Committee of the Board of Directors. No member of this committee is an officer or employee of the Company. Both the independent public accountants and internal/contract auditors have direct access to the Audit Committee and meet with the committee from time to time to discuss accounting, auditing and financial reporting matters. Effective January 1, 1994, Arthur Andersen & Co. has been contracted to provide operational and internal control audit services previously handled by the internal audit staff of the Company. It should be recognized that there are inherent limitations to the effectiveness of any system of internal control, including the possibility of human error and circumvention or override. Accordingly, even an effective system can provide only reasonable assurance with respect to the preparation of reliable financial statements. Furthermore, the effectiveness of an internal control system can change with circumstances. It is management's opinion that, considering the criteria for effective internal control over financial reporting which consists of interrelated components including the control environment, risk-assessment process, control activities, information and communication systems, and monitoring, the Company maintained an effective system of internal control over the preparation of published interim and annual financial statements for all periods presented. BEN B. BOYD WALTER C. WILSON FORREST E. HOGLUND Vice President and Senior Vice President and Chairman of the Board, Controller Chief Financial Officer President and Chief Executive Officer Houston, Texas March 18, 1994 F-2 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS To Enron Oil & Gas Company: We have audited the accompanying consolidated balance sheets of Enron Oil & Gas Company (a Delaware corporation) and subsidiaries as of December 31, 1993 and 1992, and the related consolidated statements of income, shareholders' equity and cash flows for each of the three years in the period ended December 31, 1993. These financial statements and the schedules referred to below are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and schedules based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Enron Oil & Gas Company and subsidiaries as of December 31, 1993 and 1992, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. Our audits were made for the purpose of forming an opinion on the basic financial statements taken as a whole. The financial statement schedules listed in the index to financial statements are presented for purposes of complying with the Securities and Exchange Commission's rules and are not part of the basic financial statements. These schedules have been subjected to the auditing procedures applied in the audits of the basic financial statements and, in our opinion, fairly state in all material respects the financial data required to be set forth therein in relation to the basic financial statements taken as a whole. As explained in Note 7 to the consolidated financial statements, the Company adopted Statement of Financial Accounting Standards No. 109, 'Accounting for Income Taxes', effective January 1, 1993, and applied the provisions of the statement retroactively. ARTHUR ANDERSEN & CO. Houston, Texas February 18, 1994 (except with respect to the matters discussed in Note 3, as to which the date is March 11, 1994) F-3 ENRON OIL & GAS COMPANY CONSOLIDATED STATEMENTS OF INCOME (IN THOUSANDS EXCEPT PER SHARE AMOUNTS) YEAR ENDED DECEMBER 31, 1993 1992 1991 (RESTATED) NET OPERATING REVENUES Natural Gas Associated Companies----------- $ 279,921 $ 280,501 $ 275,362 Trade-------------------------- 225,241 108,487 46,241 Crude Oil, Condensate and Natural Gas Liquids Associated Companies----------- 38,953 38,775 41,237 Trade-------------------------- 16,881 20,152 21,599 Other----------------------------- 6,706 5,074 3,166 Total-------------------- 567,702 452,989 387,605 OPERATING EXPENSES Lease and Well-------------------- 59,344 49,406 49,922 Exploration----------------------- 36,921 33,278 31,470 Dry Hole-------------------------- 18,355 10,764 14,698 Impairment of Unproved Oil and Gas Properties---------------------- 20,467 15,136 12,791 Depreciation, Depletion and Amortization-------------------- 249,704 179,839 160,885 General and Administrative-------- 45,274 36,648 36,216 Taxes Other Than Income----------- 35,396 28,346 18,222 Total-------------------- 465,461 353,417 324,204 OPERATING INCOME--------------------- 102,241 99,572 63,401 OTHER INCOME------------------------- 19,953 2,561 11,768 INCOME BEFORE INTEREST EXPENSE AND TAXES------------------------------ 122,194 102,133 75,169 INTEREST EXPENSE Incurred Affiliate---------------------- - 1,747 9,503 Other-------------------------- 15,378 24,122 24,479 Capitalized----------------------- (5,457) (3,580) (4,482) Net Interest Expense----------- 9,921 22,289 29,500 INCOME BEFORE INCOME TAXES----------- 112,273 79,844 45,669 INCOME TAX BENEFIT------------------- (25,752) (17,736) (2,247) NET INCOME--------------------------- $ 138,025 $ 97,580 $ 47,916 EARNINGS PER SHARE OF COMMON STOCK------------------------------ $ 1.73 $ 1.26 $ .63 AVERAGE NUMBER OF COMMON SHARES------ 79,983 77,267 75,900 The accompanying notes are an integral part of these consolidated financial statements. F-4 ENRON OIL & GAS COMPANY CONSOLIDATED BALANCE SHEETS (IN THOUSANDS) AT DECEMBER 31, 1993 1992 (RESTATED) ASSETS CURRENT ASSETS Cash and Cash Equivalents--------- $ 103,129 $ 132,618 Accounts Receivable Associated Companies----------- 59,143 50,838 Trade-------------------------- 66,109 50,832 Inventories----------------------- 14,082 9,534 Other----------------------------- 6,962 3,190 Total----------------------- 249,425 247,012 OIL AND GAS PROPERTIES (Successful Efforts Method)---------------------- 2,772,220 2,475,371 Less: Accumulated Depreciation, Depletion and Amortization------ 1,226,175 1,007,360 Net Oil and Gas Properties---------------- 1,546,045 1,468,011 OTHER ASSETS------------------------- 15,692 15,989 TOTAL ASSETS------------------------- $ 1,811,162 $ 1,731,012 LIABILITIES AND SHAREHOLDERS' EQUITY CURRENT LIABILITIES Accounts Payable Associated Companies----------- $ 13,250 $ 1,889 Trade-------------------------- 143,542 128,695 Accrued Taxes Payable------------- 17,354 9,911 Dividends Payable----------------- 4,795 4,800 Current Maturities of Long-Term Debt---------------------------- 30,000 - Other----------------------------- 8,989 49,421 Total----------------------- 217,930 194,716 LONG-TERM DEBT----------------------- 153,000 150,000 OTHER LIABILITIES-------------------- 9,477 8,972 DEFERRED INCOME TAXES---------------- 270,154 248,943 DEFERRED REVENUE--------------------- 227,528 301,395 COMMITMENTS AND CONTINGENCIES (Note 8) SHAREHOLDERS' EQUITY Common Stock, No Par, 80,000,000 Shares Authorized and Issued---- 200,800 200,800 Additional Paid In Capital-------- 417,531 421,747 Cumulative Foreign Currency Translation Adjustment---------- (6,855) (1,726) Retained Earnings----------------- 324,995 206,165 Common Stock Held in Treasury, 80,000 shares------------------- (3,398) - Total Shareholders' Equity---------------------- 933,073 826,986 TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY----------------------------- $ 1,811,162 $ 1,731,012 The accompanying notes are an integral part of these consolidated financial statements. F-5 ENRON OIL & GAS COMPANY CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (IN THOUSANDS EXCEPT PER SHARE AMOUNTS)
CUMULATIVE FOREIGN COMMON TOTAL ADDITIONAL CURRENCY STOCK SHAREHOLD- COMMON PAID IN TRANSLATION RETAINED HELD IN ERS' STOCK CAPITAL ADJUSTMENT EARNINGS TREASURY EQUITY (RESTATED) Balance at December 31, 1990--------- $ 200,759 $ 310,504 $ 6,540 $ 92,239 $ - $ 610,042 Net Income, as Restated----------- - - - 47,916 - 47,916 Dividends Paid/Declared, $.20 Per Share--------------------------- - - - (15,180) - (15,180) Translation Adjustment------------ - - 407 - - 407 Balance at December 31, 1991--------- 200,759 310,504 6,947 124,975 - 643,185 Net Income------------------------ - - - 97,580 - 97,580 Shares Issued by Public Offering-- 41 111,820 - - - 111,861 Dividends Paid, $.05 Per Share in April, July and October, and Declared, $.06 in December------ - - - (16,390) - (16,390) Translation Adjustment------------ - - (8,673) - - (8,673) Treasury Stock Purchased---------- - - - - (1,827) (1,827) Treasury Stock Issued Under Stock Option Plan--------------------- - (577) - - 1,827 1,250 Balance at December 31, 1992--------- 200,800 421,747 (1,726) 206,165 - 826,986 Net Income----------------------- - - - 138,025 - 138,025 Dividends Paid/Declared, $.24 Per Share-------------------------- - - - (19,195) - (19,195) Translation Adjustment----------- - - (5,129) - - (5,129) Treasury Stock Purchased--------- - - - - (16,698) (16,698) Treasury Stock Issued Under Stock Option Plan-------------------- - (4,216) - - 13,300 9,084 Balance at December 31, 1993--------- $ 200,800 $ 417,531 $ (6,855) $ 324,995 $ (3,398) $ 933,073 The accompanying notes are an integral part of these consolidated financial statements.
F-6 ENRON OIL & GAS COMPANY CONSOLIDATED STATEMENTS OF CASH FLOWS (IN THOUSANDS) YEAR ENDED DECEMBER 31, 1993 1992 1991 CASH FLOWS FROM OPERATING ACTIVITIES (RESTATED) Reconciliation of Net Income to Net Operating Cash Inflows: Net Income------------------------ $ 138,025 $ 97,580 $ 47,916 Items Not Requiring (Providing) Cash Depreciation, Depletion and Amortization----------------- 249,704 179,839 160,885 Impairment of Unproved Oil and Gas Properties--------------- 20,467 15,136 12,791 Deferred Income Taxes---------- 25,612 (17,917) (11,997) Other, Net--------------------- 1,768 5,713 5,073 Exploration Expenses-------------- 36,921 33,278 31,470 Dry Hole Expenses----------------- 18,355 10,764 14,698 Gains On Sales of Oil and Gas Properties---------------------- (13,318) (6,037) (14,983) Other, Net------------------------ 1,242 (6,147) 614 Changes in Components of Working Capital and Other Liabilities Accounts Receivable------------ (24,586) (12,732) (821) Inventories-------------------- (4,548) 3,687 (19) Accounts Payable--------------- 26,208 46,327 381 Accrued Taxes Payable---------- 7,443 247 1,011 Other Liabilities-------------- 772 (2,886) (1,006) Other, Net--------------------- (44,443) 33,784 3,839 Changes in Components of Working Capital Associated with Investing and Financing Activities---------------------- 40,042 (74,232) (7,976) NET OPERATING CASH INFLOWS----------- 479,664 306,404 241,876 INVESTING CASH FLOWS Additions to Oil and Gas Properties---------------------- (383,064) (362,403) (211,673) Exploration Expenses-------------- (36,921) (33,278) (31,470) Dry Hole Expenses----------------- (18,355) (10,764) (14,698) Proceeds from Sale of Properties---------------------- 41,815 33,412 22,827 Proceeds from Sale of Volumetric Production Payment-------------- - 326,775 - Amortization of Deferred Revenue------------------------- (73,867) (25,380) - Changes in Components of Working Capital Associated with Investing Activities------------ (37,256) 74,232 7,976 Other, Net------------------------ (4,905) (3,686) (3,020) NET INVESTING CASH OUTFLOWS---------- (512,553) (1,092) (230,058) FINANCING CASH FLOWS Long-Term Debt Affiliate---------------------- - (132,836) (145,082) Other-------------------------- 33,000 (139,556) 149,114 Common Stock Issued--------------- - 111,861 - Dividends Paid-------------------- (19,200) (15,385) (15,180) Treasury Stock Purchased---------- (16,698) (1,827) - Proceeds from Sales of Treasury Stock--------------------------- 9,084 1,250 - Other, Net------------------------ (2,786) - (466) NET FINANCING CASH INFLOWS (OUTFLOWS)------------------------- 3,400 (176,493) (11,614) INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS------------------------ (29,489) 128,819 204 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR------------------ 132,618 3,799 3,595 CASH AND CASH EQUIVALENTS AT END OF YEAR------------------------------- $ 103,129 $ 132,618 $ 3,799 The accompanying notes are an integral part of these consolidated financial statements. F-7 ENRON OIL & GAS COMPANY NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (DOLLARS IN THOUSANDS UNLESS OTHERWISE INDICATED) 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES PRINCIPLES OF CONSOLIDATION. The consolidated financial statements of Enron Oil & Gas Company (the 'Company'), 80% of the outstanding common stock of which is owned by Enron Corp., include the accounts of all domestic and foreign subsidiaries. All material intercompany accounts and transactions have been eliminated. Certain reclassifications have been made to consolidated financial statements for prior years to conform with the current presentation. CASH EQUIVALENTS. The Company records as cash equivalents all highly liquid short-term investments with maturities of three months or less. (See Note 3 'Long-Term Debt, Financing Arrangements with Enron Corp.') OIL AND GAS OPERATIONS. The Company accounts for its natural gas and crude oil exploration and production activities under the successful efforts method of accounting. Oil and gas lease acquisition costs are capitalized when incurred. Unproved properties with significant acquisition costs are assessed quarterly on a property-by-property basis and any impairment in value is recognized. Unproved properties with acquisition costs that are not individually significant are aggregated, and the portion of such costs estimated to be nonproductive, based on historical experience, is amortized over the average holding period. If the unproved properties are determined to be productive, the appropriate related costs are transferred to proved oil and gas properties. Lease rentals are expensed as incurred. Oil and gas exploration costs, other than the costs of drilling exploratory wells, are charged to expense as incurred. The costs of drilling exploratory wells are capitalized pending determination of whether they have discovered proved commercial reserves. If proved commercial reserves are not discovered, such drilling costs are expensed. The costs of all development wells and related equipment used in the production of crude oil and natural gas are capitalized. Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. Estimated future dismantlement, restoration and abandonment costs (classified as long-term liabilities), net of salvage values, are taken into account. Certain other assets are depreciated on a straight-line basis. Inventories, consisting primarily of tubular goods and well equipment held for use in the exploration for, and development and production of crude oil and natural gas reserves, are carried at cost with selected adjustments made from time to time to recognize changes in condition value. Natural gas revenues are recorded to recognize that during the course of normal production operations joint interest owners will, from time to time, take more or less than their ultimate share of natural gas volumes from jointly owned reservoirs. These volumetric imbalances are monitored over the life of the reservoir to achieve balancing, or minimize imbalances, by the time reserves are depleted. Final cash settlements are made, generally at the time a property is depleted, under one of a variety of arrangements generally accepted by the industry depending on the specific circumstances involved. The Company accrues revenues associated with undertakes and defers revenues associated with overtakes to recognize these potential ultimate imbalances. ACCOUNTING FOR FUTURES CONTRACTS. Futures transactions are entered into as hedges of commodity prices associated with the sales and purchases of natural gas and crude oil, in order to mitigate the risk of market price fluctuations. Changes in the market value of futures transactions entered into as hedges are deferred until the gain or loss is recognized on the hedged transactions. F-8 CAPITALIZED INTEREST COSTS. Certain interest costs have been capitalized as a part of the historical cost of unproved oil and gas properties. Interest costs capitalized during each of the three years in the period ended December 31, 1993 are set out in the Consolidated Statements of Income. INCOME TAXES. Taxable income of the Company, excluding that of any foreign subsidiaries, is included in the consolidated federal income tax return filed by Enron Corp. Pursuant to a tax allocation agreement between the Company, the Company's subsidiaries and Enron Corp., either Enron Corp. will pay to the Company and each subsidiary an amount equal to the tax benefit realized in the Enron Corp. consolidated federal income tax return resulting from the utilization of the Company's or the subsidiary's net operating losses and/or tax credits, or the Company and each subsidiary will pay to Enron Corp. an amount equal to the federal income tax computed on its separate taxable income less the tax benefits associated with any net operating losses and/or tax credits generated by the Company or the subsidiary which are utilized in the Enron Corp. consolidated return. Enron Corp. will pay the Company and each subsidiary for the tax benefits associated with their net operating losses and tax credits utilized in the Enron Corp. consolidated return, provided that a tax benefit was realized except as discussed in the following paragraph, even if such benefits could not have been used by the Company or the subsidiary on a separately filed tax return. In 1991, the Company and Enron Corp. modified the tax allocation agreement to provide that through 1992, the Company would realize the benefit of certain tight gas sand tax credits available to the Company on a stand alone basis. The Company has also entered into an agreement with Enron Corp. providing for the Company to be paid for all realizable benefits associated with tight gas sand tax credits concurrent with tax reporting and settlement for the periods in which they are generated. The tax allocation agreement applies to the Company and each of its subsidiaries for all years in which the Company or any of its subsidiaries are or were included in the Enron Corp. consolidated return. Taxes for any foreign subsidiaries of the Company are calculated on a separate return basis. The Company adopted the provisions of Statement of Financial Accounting Standards (SFAS) No. 109 -'Accounting for Income Taxes' effective January 1, 1993 and applied the provisions of the statement retroactively. The Company previously accounted for income taxes under the provisions of SFAS No. 96 which was superceded by SFAS No. 109. SFAS No. 109 retains the asset and liability approach for accounting for income taxes. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax bases. FOREIGN CURRENCY TRANSLATION. For subsidiaries whose functional currency is deemed to be other than the U.S. dollar, asset and liability accounts are translated at year end rates of exchange and revenue and expenses are translated at average exchange rates prevailing during the year. Translation adjustments are included as a separate component of shareholders' equity. EARNINGS PER SHARE. Earnings per share is computed on the basis of the average number of common shares outstanding during the periods. F-9 2. NATURAL GAS AND CRUDE OIL, CONDENSATE AND NATURAL GAS LIQUIDS NET OPERATING REVENUES Natural Gas Net Operating Revenues are comprised of the following: 1993 1992 1991 Wellhead Natural Gas Revenues Associated Companies(1)---------- $340,508(2) $223,249(2) $171,056 Trade---------------------------- 156,301 103,288 75,037 Total-------------------- $496,809 $326,537 $246,093 Other Natural Gas Marketing Activities Gross Revenues from: Associated Companies(3)------ $139,576 $186,600 $220,152 Trade------------------------ 135,606(4) 57,482(4) 7,215 Total-------------------- 275,182 244,082 227,367 Associated Costs from: Associated Companies(1)(5)-------------- 182,456(6) 133,170(6) 115,601 Trade------------------------ 66,273 52,283 36,011 Total-------------------- 248,729 185,453 151,612 Net---------------------- 26,453 58,629 75,755 NYMEX Commodity Price Hedging Gain (Loss)(7)----------------- (18,100) 3,822 (245) Total-------------------- $ 8,353 $ 62,451 $ 75,510 Crude Oil, Condensate and Natural Gas Liquids Net Operating Revenues are comprised of the following: 1993 1992 1991 Wellhead Crude Oil, Condensate and Natural Gas Liquids Revenues Associated Companies------------- $ 38,953 $ 38,474 $ 37,029 Trade---------------------------- 16,881 20,152 21,599 Total------------------------ $ 55,834 $ 58,626 $ 58,628 Other Crude Oil and Condensate Marketing Activities NYMEX Commodity Price Hedging Gain(7)------------------------ $ - $ 301 $ 4,208 (1) Wellhead Natural Gas Revenues in 1993, 1992 and 1991 include $129,504, $84,317 and $69,175, respectively, associated with deliveries by Enron Oil & Gas Company to Enron Oil & Gas Marketing, Inc., a wholly-owned subsidiary, reflected as a cost in Other Natural Gas Marketing Activities -Associated Costs. (2) Includes $46,358 and $20,667 in 1993 and 1992, respectively, associated with the equivalent wellhead value of volumes delivered under the terms of a volumetric production payment agreement effective October 1, 1992, as amended, net of transportation. (3) Includes the effect of a price swap agreement with an Enron Corp. affiliated company which in effect fixed the price of certain sales. (4) Includes $73,867 and $25,380 in 1993 and 1992, respectively, associated with the amortization of deferred revenues under the terms of volumetric production payment and exchange agreements effective October 1, 1992, as amended. (5) Includes the effect of a price swap agreement with a third party which in effect fixed the price of certain purchases. (6) Includes $65,042 and $23,977 in 1993 and 1992, respectively, for volumes delivered under volumetric production payment and exchange agreements effective October 1, 1992, as amended, including equivalent wellhead value, any applicable transportation costs and exchange differentials. (7) Represents gain or loss associated with commodity futures transactions primarily with Enron Corp. affiliated companies based on NYMEX prices in effect on dates of execution, less customary transaction fees. F-10 3. LONG-TERM DEBT REVOLVING CREDIT AGREEMENT. In March 1994, the Company replaced an existing credit agreement with a Revolving Credit Agreement dated as of March 11, 1994, among the Company and the banks named therein (the 'Credit Agreement'). The Credit Agreement provides for aggregate borrowings of up to $100 million, with provisions for increases, at the option of the Company, up to $300 million. Advances under the Credit Agreement bear interest, at the option of the Company, based on a base rate, an adjusted CD rate or a Eurodollar rate. Each advance under the Credit Agreement matures on a date selected by the Company at the time of the advance, but in no event after January 15, 1998. FINANCING ARRANGEMENTS WITH ENRON CORP. The Company engages in various transactions with Enron Corp. that are characteristic of a consolidated group under common control. Activities of the Company not internally funded from operations have been and may be funded from time to time by advances from Enron Corp. The Company entered into an agreement with Enron Corp., effective October 12, 1989 (as amended effective September 29, 1992), under which the Company may borrow funds from Enron Corp. at a representative market rate of interest on a revolving basis. During 1993, there were no funds borrowed by the Company under this agreement. Any loan balance that may be outstanding from time to time is payable on demand but no later than September 29, 1995, the maturity date of this agreement. Any balances outstanding are classified as long-term based on the Company's intent and ability to refinance such amounts using available borrowing capacity. Interest expense recorded in 1992 and 1991 under the terms of this agreement totaled $.1 million and $.2 million, respectively. There was no interest expense relating to this agreement recorded in 1993. The Company also entered into an agreement with Enron Corp., effective October 12, 1989 (as amended effective September 29, 1992), which provides the Company the option of depositing any excess funds that may be available from time to time with Enron Corp. with interest at a representative market rate during the periods the funds were held by Enron Corp. Interest income recorded in 1992 and 1991 under the terms of this agreement totaled $1.4 million and $.3 million, respectively. Effective January 1, 1993, the Company executed a promissory note at a fixed interest rate of 7% with Enron Corp. providing for the investment of funds temporarily surplus to the Company from time to time with Enron Corp. Daily outstanding balances of funds advanced to Enron Corp. under this note averaged $60.3 million during 1993 with a balance of $96.6 million outstanding and included in Cash and Cash Equivalents at December 31, 1993. Interest income recorded in 1993 under the terms of this note totaled $4.4 million. OTHER LONG-TERM DEBT. Other long-term debt at December 31 consisted of the following: 1993 1992 Loans Payable-------------------- $ 50,000 $ 50,000 Senior Notes--------------------- 70,000 100,000 Promissory Note------------------ 33,000 - Total---------------- $ 153,000 $ 150,000 The Loans Payable are due in 1995 and bear interest at a variable rate based on the London Interbank Offered Rate which has, in effect, been converted to fixed interest rates ranging from 8.92% to 8.98% through maturity using interest rate swap agreements in equivalent dollar amounts. The Senior Notes bear interest at 9.1% with principal repayments of $30 million due in 1996 and $20 million due in 1997 and 1998. A principal repayment of $30 million is due in 1994 and is classified as current maturities of long-term debt at December 31, 1993. The Promissory Note is payable by one of the Company's subsidiaries to a bank, bears interest at 3 3/8% and represents interim financing under Section 936(d)(4) of the Internal Revenue Code of 1986, as amended, of a project involving the development of gas and oil fields. The note is due the earlier of April 30, 1994, as extended, or the closing date of the permanent financing and is collateralized with a letter of credit issued by a bank on behalf of the subsidiary and guaranteed by the Company. The note F-11 is classified as long-term based on the subsidiary's intent and ability to convert the balance of the note to permanent long-term financing. In March 1994, the subsidiary received two advances aggregating $31 million under a credit agreement dated as of March 8, 1994, between the subsidiary and a financial institution. The credit agreement provides for aggregate borrowings of up to $75 million. One of the advances is in the amount of $16 million, bears interest at a fixed rate of 4.52% and is due in 1998. The other advance is in the amount of $15 million, bears interest at a floating rate that resets quarterly equal to 84% of the LIBID Rate which is 1/8 of 1% less than the London Interbank Offered Rate and is due in 1998. Both advances are collaterized with a letter of credit issued by a bank on behalf of the subsidiary and guaranteed by the Company. The advances were used to partially repay the Promissory Note. There were no balances outstanding at December 31, 1993 and 1992 under a commercial paper program initiated in 1990. The proceeds from the commercial paper program outstanding from time to time are used to fund current transactions. Certain of the borrowings described above contain covenants requiring the maintenance of certain financial ratios and limitations on liens, debt issuance and dispositions of assets. In September 1991, the Company filed with the Securities and Exchange Commission a registration statement providing for the issuance and sale from time to time of up to $250 million of debt securities to the public. As of December 31, 1993, no debt securities had been issued under this registration statement. 4. DEFERRED REVENUE In September 1992, the Company sold a volumetric production payment for $326.8 million to a limited partnership of which an Enron Corp. affiliated company is general partner with a 1% interest. Under the terms of the production payment agreements, the Company conveyed a real property interest of approximately 124 billion cubic feet equivalent ('Bcfe') (136 trillion British thermal units) of natural gas and other hydrocarbons in the Big Piney area of Wyoming. The natural gas and other hydrocarbons were originally scheduled to be produced and delivered over a period of forty-five months which period commenced October 1, 1992. Effective October 1, 1993, the agreements were amended providing for the extension of the original term of the volumetric production payment through March 31, 1999 and including a revised schedule of daily quantities of hydrocarbons to be delivered which is approximately one-half of the original schedule. The revised schedule will total approximately 89.1 Bcfe (97.8 trillion British thermal units) versus approximately 87.9 Bcfe (96.4 trillion British thermal units) remaining to be delivered under the original agreement. Daily quantities of hydrocarbons no longer required to be delivered under the revised schedule during the period from October 1, 1993 through June 30, 1996 are available for sale by the Company. The Company retains responsibility for its working interest share of the cost of operations. The Company also entered into a separate agreement with the same limited partnership whereby it has agreed to exchange volumes owned by the Company in the Midcontinent area and the Texas Gulf Coast area for equivalent volumes produced and owned by the limited partnership in the Big Piney area. The costs incurred, if any, to effect redeliveries pursuant to such exchange are borne by the Company. A portion of the proceeds of the sale was used to repay a portion of the Company's long-term debt, with surplus funds advanced to Enron Corp. under a note agreement which facilitates the deposit of funds temporarily surplus to the Company. The Company accounted for the proceeds received in the transaction as deferred revenue which is being amortized into revenue and income as natural gas and other hydrocarbons are produced and delivered during the term, as revised, of the volumetric production payment. Annual remaining amortization of deferred revenue, based on revised F-12 scheduled deliveries under the volumetric production payment agreement, as amended, at December 31, 1993 was as follows: 1994--------------------------------- $ 43,344 1995--------------------------------- 43,344 1996--------------------------------- 43,463 1997--------------------------------- 43,344 1998--------------------------------- 43,344 1999--------------------------------- 10,689 Total------------------------ $ 227,528 5. SHAREHOLDERS' EQUITY In August 1992, the Company completed the offering and sale of 4.1 million shares of common stock. The shares were priced to the public at $28.50 per share. Net proceeds, after underwriting commissions and expenses, totaled approximately $112 million and were used primarily to repay long-term debt. In December 1992, the Board of Directors of the Company approved the reduction of the authorized common shares from 100 million to 80 million shares and cancelled the authorization for preferred shares. Such actions were approved by the shareholders in May 1993. Also in December 1992, the Board of Directors of the Company approved the purchase of up to 250,000 shares of common stock of the Company for, but not limited to, meeting obligations associated with stock option grants to qualified employees pursuant to the Enron Oil & Gas Company 1992 Stock Plan. (See Note 8 'Commitments and Contingencies -Enron Oil & Gas Company 1992 Stock Plan'). At December 31, 1993, 80,000 shares were held in treasury under this authorization. In February 1994, the Board of Directors authorized submission of a resolution to shareholders for approval at their annual meeting in May 1994 that would, contingent upon the Board of Directors of the Company declaring, on or before May 3, 1995, a stock split of either two-for-one or three-for-two, amend the Restated Certificate of Incorporation of the Company to increase the total number of authorized shares of the common stock of the Company from 80 million to 160 million shares in the event of a two-for-one stock split or to 120 million shares in the event of a three-for-two stock split. Such charter amendment, if adopted, will become effective when the appropriate Certificate of Amendment to the Company's Restated Certificate of Incorporation is filed with the Secretary of State of Delaware, which filing will only be authorized at such time as the Board of Directors takes the requisite action to approve either a two-for-one or a three-for-two stock split in either case effected as a dividend which action, if to be carried out under this resolution, must occur on or before May 3, 1995. 6. TRANSACTIONS WITH ENRON CORP. AND RELATED PARTIES NATURAL GAS AND CRUDE OIL, CONDENSATE AND NATURAL GAS LIQUIDS NET OPERATING REVENUES. Wellhead Natural Gas and Crude Oil, Condensate and Natural Gas Liquids Revenues and Other Natural Gas and Other Crude Oil and Condensate Marketing Activities include revenues from and associated costs paid to various subsidiaries and affiliates of Enron Corp. pursuant to contracts which, in the opinion of management, are no less favorable than could be obtained from third parties. Other Natural Gas and Other Crude Oil and Condensate Marketing Activities also include certain price swap and futures transactions with Enron Corp. affiliated companies which, in the opinion of management, are no less favorable than could be obtained from third parties. (See Note 2 'Natural Gas and Crude Oil, Condensate and Natural Gas Liquids Net Operating Revenues'). GENERAL AND ADMINISTRATIVE EXPENSES. The Company is charged by Enron Corp. for all direct costs associated with its operations. Such direct charges, excluding benefit plan charges (See Note 8 'Commitments and Contingencies -Employee Benefit Plans'), totaled $11.5 million, $4.9 million and $7.4 million for the years ended December 31, 1993, 1992 and 1991, respectively. Management believes that these charges are reasonable. F-13 Additionally, certain administrative costs not directly charged to any Enron Corp. operations or business segments are allocated to the entities of the consolidated group. Allocation percentages are generally determined utilizing weighted average factors derived from property gross book value, net operating revenues and payroll costs. Effective January 1, 1989, the Company entered into an agreement with Enron Corp., with an initial term of five years, providing for, among other things, an annual cap of $8.0 million to be applied to indirect allocated charges subject to adjustment for inflation and certain changes in the allocation bases of the Company. Approximately $7.9 million, $9.5 million, and $9.4 million were charged to the Company for indirect general and administrative expenses for the years ended December 31, 1993, 1992 and 1991, respectively. Management believes the indirect allocated charges for the numerous types of support services provided by the corporate staff are reasonable. Effective January 1, 1994, the Company and Enron Corp. entered into a new services agreement pursuant to which Enron Corp. will, among other things, provide for the Company similar services substantially identical in nature and quality to those provided under terms of the previous agreement. The Company has agreed to pay and to reimburse Enron Corp. on bases essentially consistent with those included in the previous agreement, except that allocated indirect costs are subject to an annual maximum of $6.7 million for the year 1994 with any increase in such maximum for subsequent years not to exceed 7.5% per year. The new services agreement is for an initial term of five years through December 1998 and will continue thereafter until terminated by either party. FINANCING. See Note 3 'Long-Term Debt' for a discussion of financing arrangements with Enron Corp. 7. INCOME TAXES As discussed in Note 1, effective January 1, 1993, the Company adopted SFAS No. 109 and applied the provisions of the statement retroactively. Under the provisions of SFAS No. 109, the effect of a change in a tax rate is recognized in income for the period that includes the date of enactment of such change. Consequently, the previously reported net income for 1991 was restated to $47.9 million ($.63 per share) from $54.9 million ($.72 per share), a reduction of $7.0 million primarily to recognize the enactment of a change in the computation of certain state franchise taxes, a portion of which is treated as an income tax under SFAS No. 109. Net income for 1992 and 1993 was not affected by the restatement. The Company's consolidated balance sheet at December 31, 1992 was also restated to reflect the increase to Deferred Income Taxes of $7.0 million and the corresponding decrease to Retained Earnings of an equal amount. In August 1993, the corporate federal income tax rate increased from 34% to 35% retroactive to January 1, 1993 resulting in an increase to the Company's 1993 deferred income tax provision of approximately $5.9 million with a corresponding increase to the Company's deferred income tax liability of an equal amount and a decrease of approximately $1.2 million to the Company's 1993 current income tax benefit. F-14 The principal components of the Company's net deferred income tax liability at December 31, 1993 and 1992 were as follows (in thousands): 1993 1992 (RESTATED) Deferred Income Tax Assets Non-Producing Leasehold Costs------ $ 5,234 $ 4,661 Seismic Costs Capitalized for Tax------------------------------ 5,643 6,505 Other------------------------------ 6,337 13,167 Total Deferred Income Tax Assets----------------------- 17,214 24,333 Deferred Income Tax Liabilities Oil & Gas Exploration and Development Costs Deducted for Tax Over Book Depreciation, Depletion and Amortization------- 276,422 253,009 Capitalized Interest--------------- 6,866 4,604 Other------------------------------ 4,080 15,663 Total Deferred Income Tax Liabilities------------------ 287,368 273,276 Net Deferred Income Tax Liability-------------------- $ 270,154 $ 248,943 The components of income (loss) before income taxes were as follows: [CAPTION] 1993 1992 1991 United States------------------------ $ 117,460 $ 74,226 $ 49,187 Foreign------------------------------ (5,187) 5,618 (3,518) Total------------------------ $ 112,273 $ 79,844 $ 45,669 Total income tax provision (benefit) was as follows: 1993 1992 1991 (RESTATED) Current: Federal-------------------------- $ (52,555) $ (292) $ 9,226 State---------------------------- 5 2 - Foreign-------------------------- 1,186 471 524 Total------------------------ (51,364) 181 9,750 Deferred: Federal-------------------------- 20,845 (21,729) (23,917) State---------------------------- 4,357 3,119 11,962 Foreign-------------------------- 410 693 (42) Total------------------------ 25,612 (17,917) (11,997) Income Tax Benefit----------------- $ (25,752) $ (17,736) $ (2,247) The differences between taxes computed at the U.S. federal statutory rate and the Company's effective rate were as follows: 1993 1992 1991 (RESTATED) Statutory Federal Income Tax--------- $ 39,296 $ 27,147 $ 15,528 State Income Tax, Net of Federal Benefit---------------------------- 2,835 2,059 877 Income Tax Related to Foreign Operations------------------------- 3,461 (1,649) 1,677 Tight Gas Sand Federal Income Tax Credits---------------------------- (65,172) (42,500) (16,926) Revision of Prior Years' Tax Estimates-------------------------- (12,060) (2,842) (10,461) SFAS No. 109 Restatement------------- - - 7,018 Federal Tax Rate Increase------------ 5,875 - - Other-------------------------------- 13 49 40 Income Tax Benefit--------------- $ (25,752) $ (17,736) $ (2,247) F-15 Current income tax receivable from (payable to) Enron Corp. at December 31, 1993, 1992 and 1991 amounted to $(6,892), $5,619 and $(4,522), respectively. The Company has an alternative minimum tax (AMT) credit carryforward of $2.7 million which can be used to offset regular income taxes payable in future years. The AMT credit carryforward has an indefinite carryforward period. The Company's foreign subsidiaries' undistributed earnings of approximately $45 million at December 31, 1993 are considered to be indefinitely invested outside the U.S. and, accordingly, no U.S. federal or state income taxes have been provided thereon. Upon distribution of those earnings in the form of dividends, the Company may be subject to both foreign withholding taxes and U.S. income taxes, net of allowable foreign tax credits. Determination of any potential amount of unrecognized deferred income tax liabilities is not practicable. In 1991, the Company recognized for financial reporting purposes the benefits attributable to the utilization of a previously unrecognized separate company net operating loss carryforward resulting in a tax benefit of approximately $7 million reflected in 1991 net income. 8. COMMITMENTS AND CONTINGENCIES EMPLOYEE BENEFIT PLANS. Employees of the Company are covered by various retirement, stock purchase and other benefit plans of Enron Corp. During each of the years ended December 31, 1993, 1992 and 1991, the Company was charged $4.5 million, $3.6 million and $3.6 million, respectively, for all such benefits, including pension expense totalling $.5 million, $.5 million and $.4 million, respectively, by Enron Corp. As of September 30, 1993, the most recent valuation date, the plan net assets of the Enron Corp. defined benefit plan in which the employees of the Company participate exceeded the actuarial present value of projected plan benefit obligations by approximately $25.3 million. The assumed discount rate, rate of return on plan assets and rate of increases in wages used in determining the actuarial present value of projected plan benefits were 7.0%, 10.5% and 4.0%, respectively. The Company also has in effect a pension and a savings plan related to its Canadian and Trinidadian subsidiaries. Activity related to these plans is not significant to the Company's operations. The Company provides certain medical, life insurance and dental benefits to eligible employees who retire under the Enron Corp. Retirement Plan and their eligible surviving spouses. Effective January 1, 1993, the Company adopted the provisions of SFAS No. 106 'Employers' Accounting for Postretirement Benefits Other Than Pensions'. The standard requires that employers providing postretirement benefits accrue those costs over the service lives of the employees expected to be eligible to receive such benefits. Such costs were previously recorded on a pay-as-you-go basis. The net periodic cost under SFAS No. 106 for 1993 was approximately $1.0 million, including service cost, interest cost and amortization of transition obligation in the amounts of $.1 million, $.5 million and $.4 million, respectively. The transition obligation existing at January 1, 1993 is being amortized over an average period of 19 years. The adoption of SFAS No. 106 did not have a material impact on the Company's results of operations. The accumulated postretirement benefit obligation ('APBO') existing at December 31, 1993 totaled $8.7 million, of which $7.2 million is applicable to current retirees and current employees eligible to retire. The measurement of the APBO assumes a 7% discount rate and a health care cost trend rate of 13% in 1993 decreasing to 5% by the year 2005 and beyond. A 1% increase in the health care cost trend rate would have the effect of increasing the APBO and the net periodic expense by approximately $.8 million and $.1 million, respectively. The Company does not currently intend to prefund its obligations under its postretirement welfare benefit plans. ENRON OIL & GAS COMPANY 1992 STOCK PLAN. In December 1991, the Board of Directors of the Company adopted the Enron Oil & Gas Company 1992 Stock Plan (the 'Stock Plan'). The Stock Plan was approved by the shareholders in May 1992. Under the Stock Plan, employees of the F-16 Company and its subsidiaries may be granted rights to purchase shares of common stock of the Company generally at a price not less than the market price of the stock at the date of grant. Options granted under the Stock Plan vest to the employee over a period of time based on the nature of the grants and as defined in the individual grant agreements. The following table sets forth Stock Plan transactions for the years ended December 31: NUMBER OF STOCK OPTIONS 1993 1992 Outstanding at January 1------------- 1,954,025 - Granted-------------------------- 460,300 2,024,025 Exercised------------------------ (335,925) (63,750) Forfeited------------------------ (16,000) (6,250) Outstanding at December 31 (Grant Prices of $18.50-$47.63 per Share)- 2,062,400 1,954,025 Available for Grant at December 31--- 537,925 982,225 At December 31, 1993, 1,249,975 of the Stock Plan options outstanding were vested. Of the remaining unvested Stock Plan options, approximately 377,550; 201,750; 157,375 and 75,750 vest in the years 1994, 1995, 1996 and 1997, respectively. During 1993 and 1992, the Company purchased 335,925 and 63,750 of its common shares, respectively, and simultaneously delivered such shares upon the exercise of stock options. The difference between the cost of the treasury shares and the exercise price of the options, net of federal income tax benefit of $2.8 million, is reflected as an adjustment to Additional Paid In Capital. In addition in October 1993, the Company commenced a stock repurchase program authorized by the Board of Directors to facilitate the availability of treasury shares of common stock for the settlement of employee stock option exercises pursuant to, but not limited to, the Enron Oil & Gas Company 1992 Stock Plan. At December 31, 1993, 80,000 shares were held in treasury under this authorization. (See Note 5 'Shareholders' Equity'). Pursuant to an amendment to and extension of an employment agreement with the Chairman of the Board, President and Chief Executive Officer of the Company (the 'Chairman'), as of January 1, 1992, the Chairman agreed to the cancellation of 1,000,000 previously issued stock appreciation right ('SAR') units. The Chairman was granted 1,110,000 stock options pursuant to the 1992 Stock Plan. These options have a grant price of $18.50 per share; 1,000,000 of the options follow the same vesting schedule as did the SAR unit grant, 100,000 options vest over four years and the remaining 10,000 options vested in one year since such options were granted in lieu of part of the Chairman's 1991 cash bonus. In addition, the Chairman was issued in May 1992, 463,320 shares of Enron Corp. common stock. Such number of shares reflects the effect of a two-for-one split of such stock on August 16, 1993. Of these shares, 370,656 shares are restricted until such shares vest on the earlier to occur of five years after their date of grant or when the Chairman commences receiving benefits from one or more of the qualified pension plans sponsored by Enron Corp. In February 1994, the Board of Directors of the Company adopted the Enron Oil & Gas Company 1994 Stock Plan (the '1994 Stock Plan'). Under the 1994 Stock Plan, employees of the Company and its subsidiaries may be granted rights to purchase shares of common stock of the Company generally at a price not less than the market price of the stock at the date of grant. Options granted under the 1994 Stock Plan vest to the employee over a period of time based on the nature of the grants and as defined in the individual grant agreements. The number of shares available for granting awards under the 1994 Stock Plan is 1,000,000 shares subject to certain adjustments. It is the intention of the Company that grants under the 1994 Stock Plan will be primarily to non-executive employees. LETTERS OF CREDIT. At December 31, 1993 and 1992, the Company had letters of credit outstanding totalling approximately $46.2 and $52.9 million, respectively. The letters of credit outstanding at December 31, 1993 include $33 million issued in connection with a promissory note between one of F-17 the Company's subsidiaries and a bank. The letters of credit outstanding at December 31, 1992 included $40 million issued in December 1992 in connection with the acquisition of producing properties in Canada, which acquisition was subsequently funded in early 1993. The related liability at December 31, 1992 for the acquisition was included in Other Current Liabilities. CONTINGENCIES. There are various suits and claims against the Company having arisen in the ordinary course of business. However, management does not believe these suits and claims will individually or in the aggregate have a material adverse effect on the Company's financial condition or results of operations. TransAmerican Natural Gas Corporation ('TransAmerican') has filed a petition against the Company and Enron Corp. alleging breach of contract, tortious interference with contract, misappropriation of trade secrets and violation of state antitrust laws. The petition, as amended, seeks actual damages of $100 million plus exemplary damages of $300 million. The Company has answered the petition and is actively defending the matter; in addition, the Company has filed counterclaims against TransAmerican and a third-party claim against its sole shareholder, John R. Stanley, alleging fraud, negligent misrepresentation and breach of state antitrust laws. Trial, originally set for February 7, 1994, is now set for September 12, 1994. Although no assurances can be given, the Company believes that the claims made by TransAmerican are totally without merit, that the ultimate resolution of the matter will not have a materially adverse effect on its financial condition or results of operations, and that such ultimate resolution could result in a recovery to the Company. The Company has been named as a potentially responsible party in certain Comprehensive Environmental Response Compensation and Liability Act proceedings. However, management does not believe that any potential assessments resulting from such proceedings will individually or in the aggregate have a materially adverse effect on the financial condition or results of operations of the Company. 9. CASH FLOW INFORMATION Gains on sales of certain oil and gas properties in the amount of $13.3 million, $6.0 million and $15.0 million are required to be removed from Net Income in connection with determining Net Operating Cash Inflows while the related proceeds are classified as investing cash flows for the years ended December 31, 1993, 1992 and 1991, respectively. However, current accounting guidelines will not permit the relevant federal income tax impact of these transactions to be reclassified to investing cash flows. The current federal income tax impact of these sales transactions was calculated by the Company to be $8.2 million, $8.2 million and $5.1 million for the years ended December 31, 1993, 1992 and 1991, respectively, which entered into the overall calculation of current federal income tax. The Company believes that this federal income tax impact should be considered in analyzing the elements of the cash flow statement. Cash paid for interest and paid (received) for income taxes was as follows for the years ended December 31: 1993 1992 1991 Interest (net of amount capitalized)----------------------- $ 10,517 $ 21,576 $ 30,967 Income taxes------------------------- (67,733) 7,365 6,618 F-18 10. BUSINESS SEGMENT INFORMATION The Company's operations are all natural gas and crude oil exploration and production related. Accordingly, such operations are classified as one business segment. Financial information by geographic area is presented below for the years ended December 31, or at December 31: 1993 1992 1991 Gross Operating Revenues United States-------------------- $ 640,205 $ 521,128 $ 436,856 Foreign-------------------------- 46,722 32,997 33,186 Total(1)--------------------- $ 686,927 $ 554,125 $ 470,042 Operating Income (Loss) United States-------------------- $ 112,686 $ 109,515 $ 77,333 Foreign-------------------------- (10,445) (9,943) (13,932) Total------------------------ $ 102,241 $ 99,572 $ 63,401 Identifiable Assets United States-------------------- $1,564,330 $1,568,093 $1,309,967 Foreign-------------------------- 246,832 162,919 145,641 Total------------------------ $1,811,162 $1,731,012 $1,455,608 (1) Not deducted are natural gas associated costs of $119,225, $101,136 and $82,437 in 1993, 1992 and 1991, respectively. 11. OTHER INCOME Other income consisted of the following for the years ended December 31: 1993 1992 1991 Gains on Sales of Oil and Gas Properties------------------------- $ 13,318 $ 6,037 $ 14,983 Litigation Reserve Accruals---------- (2,520) (2,194) (1,200) Interest Income---------------------- 5,789 1,555 424 Settlement of Natural Gas Contracts-------------------------- 4,248 - - Other, Net--------------------------- (882) (2,837) (2,439) Total------------------------ $ 19,953 $ 2,561 $ 11,768 12. CONCENTRATIONS OF CREDIT RISK AND ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS ACCOUNTS RECEIVABLE. Substantially all of the Company's accounts receivable at December 31, 1993 result from crude oil and natural gas sales and/or joint interest billings to affiliate and third party companies in the oil and gas industry. This concentration of customers and joint interest owners may impact the Company's overall credit risk, either positively or negatively, in that these entities may be similarly affected by changes in economic or other conditions. In determining whether or not to require collateral from a customer or joint interest owner, the Company analyzes the entity's net worth, cash flows, earnings, and credit ratings. Receivables are generally not collateralized. Historical credit losses incurred on receivables by the Company have been immaterial. LONG-TERM DEBT. At December 31, 1993, the Company had $153 million of long-term debt and $30 million of current maturities outstanding. (See Note 3 'Long-Term Debt'). The estimated fair value of such debt, including current maturities, at December 31, 1993 was approximately $192 million. The fair value of long-term debt is the value the Company would have to pay to retire the debt, including any premium or discount to the debtholder for the differential between the stated interest rate and the year-end market rate. The fair value of long-term debt is based upon quoted market prices and, where such quotes were not available, upon interest rates available to the Company at year-end. F-19 INTEREST RATE SWAP AGREEMENTS. In early 1992, the Company entered into $75 million in notional amount of interest rate swap agreements to hedge certain floating interest rate exposure in 1992 and 1993. This floating rate exposure arises from interest-bearing debt with interest payments subject to floating interest rates. (See Note 3 'Long-Term Debt'). Effective January 1, 1993, Enron Corp. assumed the Company's remaining obligations under these swap agreements. At December 31, 1993, the Company had outstanding interest rate swaps with notional principal amounts of $50 million which terminate April 1995. The estimated fair value of the outstanding swap agreements at December 31, 1993 was a negative $3.3 million. The fair value of interest rate swap agreements is based upon termination values obtained from third parties. FOREIGN CURRENCY CONTRACTS. The Company enters into foreign currency contracts from time to time to hedge specific currency exposure from commercial transactions. At December 31, 1993, there were no foreign currency contracts outstanding. PRICE RISK MANAGEMENT. During 1990 and 1991, the Company entered into certain price swap agreements to, in effect, hedge the market risk caused by fluctuations in the price of natural gas. The agreements call for the Company to make payments to (or receive payments from) the other party based upon the differential between a fixed and a variable price for natural gas as specified by the contract. The current swap agreements run for periods of up to ten years expiring in 2000 and have a notional contract amount of approximately $299 million at December 31, 1993. While notional contract amounts are used to express the magnitude of price and interest rate swap agreements, the amounts potentially subject to credit risk, in the event of nonperformance by the third parties, are substantially smaller. The Company does not anticipate nonperformance by the third parties. F-20 ENRON OIL & GAS COMPANY SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS (IN THOUSANDS EXCEPT PER SHARE AMOUNTS UNLESS OTHERWISE INDICATED) (UNAUDITED EXCEPT FOR RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES) OIL AND GAS PRODUCING ACTIVITIES The following disclosures are made in accordance with SFAS No. 69 - 'Disclosures about Oil and Gas Producing Activities': OIL AND GAS RESERVES. Users of this information should be aware that the process of estimating quantities of 'proved' and 'proved developed' crude oil and natural gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history, and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. Proved reserves represent estimated quantities of crude oil, condensate, natural gas and natural gas liquids that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions existing at the time the estimates were made. Proved developed reserves are proved reserves expected to be recovered, through wells and equipment in place and under operating methods being utilized at the time the estimates were made. Canadian provincial royalties are determined based on a graduated percentage scale which varies with prices and production volumes. Canadian reserves, as presented on a net basis, assume prices and royalty rates in existence at the time the estimates were made, and the Company's estimate of future production volumes. Future fluctuations in prices, production rates, or changes in political or regulatory environments could cause the Company's share of future production from Canadian reserves to be materially different from that presented. Estimates of proved and proved developed reserves at December 31, 1993, 1992 and 1991 were based on studies performed by the Company's engineering staff for reserves in both the United States and Canada. Opinions by DeGolyer and MacNaughton, independent petroleum consultants, for the years ended December 31, 1993, 1992 and 1991 covering producing areas containing 65%, 69% and 73%, respectively, of proved reserves of the Company on a net-equivalent-cubic-feet-of-gas basis, indicate that the estimates of proved reserves prepared by the Company's engineering staff for the properties reviewed by DeGolyer and MacNaughton, when compared in total on a net-equivalent- cubic-feet-of-gas basis, do not differ materially from the estimates prepared by DeGolyer and MacNaughton. Such estimates by DeGolyer and MacNaughton in the aggregate varied by not more than 5% from those prepared by the Company's engineering staff. All reports by DeGolyer and MacNaughton were developed utilizing geological and engineering data provided by the Company. No major discovery or other favorable or adverse event subsequent to December 31, 1993 is believed to have caused a material change in the estimates of proved or proved developed reserves as of that date. F-21 The following table sets forth the Company's net proved and proved developed reserves at December 31 for each of the four years in the period ended December 31, 1993, and the changes in the net proved reserves for each of the three years in the period then ended as estimated by the Company's engineering staff. NET PROVED AND PROVED DEVELOPED RESERVE SUMMARY
UNITED STATES CANADA TRINIDAD TOTAL Natural Gas (MMcf) Proved reserves at December 31, 1990--------------------------- 1,343,467 131,508 - 1,474,975 Revisions of previous estimates------------------ 48,371 35 - 48,406 Purchases in place----------- 45,030 2,885 - 47,915 Extensions, discoveries and other additions------------ 199,410 6,193 - 205,603 Sales in place--------------- (6,933) (2,477) - (9,410) Production------------------- (173,460) (9,237) - (182,697) Proved reserves at December 31, 1991--------------------------- 1,455,885 128,907 - 1,584,792 Revisions of previous estimates------------------ (46,325) (4,082) - (50,407) Purchases in place----------- 30,537 112,592 - 143,129 Extensions, discoveries and other additions------------ 228,044 6,336 - 234,380 Sales in place--------------- (27,707) (2) - (27,709) Production------------------- (200,054) (11,249) - (211,303) Proved reserves at December 31, 1992--------------------------- 1,440,380(1) 232,502 - 1,672,882 Revisions of previous estimates------------------ (31,282) 11,058 - (20,224) Purchases in place----------- 9,183 2,627 - 11,810 Extensions, discoveries and other additions------------ 234,858 47,678 101,292 383,828 Sales in place--------------- (12,453) (1,501) - (13,954) Production------------------- (240,014) (21,308) (829) (262,151) Proved reserves at December 31, 1993--------------------------- 1,400,672(1) 271,056 100,463 1,772,191 Liquids (MBbl)(2) Proved reserves at December 31, 1990--------------------------- 16,272 6,856 - 23,128 Revisions of previous estimates------------------ (86) 256 - 170 Purchases in place----------- 173 42 - 215 Extensions, discoveries and other additions------------ 983 310 - 1,293 Sales in place--------------- (1,248) (25) - (1,273) Production------------------- (2,272) (927) - (3,199) Proved reserves at December 31, 1991--------------------------- 13,822 6,512 - 20,334 Revisions of previous estimates------------------ 365 (885) - (520) Purchases in place----------- 65 - - 65 Extensions, discoveries and other additions------------ 2,320 698 - 3,018 Sales in place--------------- (296) (4) - (300) Production------------------- (2,411) (963) - (3,374) Proved reserves at December 31, 1992--------------------------- 13,865(1) 5,358 - 19,223 Revisions of previous estimates------------------ 1,490 (536) - 954 Purchases in place----------- 15 489 - 504 Extensions, discoveries and other additions------------ 3,552 1,115 2,251 6,918 Sales in place--------------- (3,230) (23) - (3,253) Production------------------- (2,520) (932) (33) (3,485) Proved reserves at December 31, 1993--------------------------- 13,172(1) 5,471 2,218 20,861 (TABLE CONTINUED ON FOLLOWING PAGE) F-22 Proved developed reserves at Natural Gas (MMcf) December 31, 1990------------ 1,023,711 114,045 - 1,137,756 December 31, 1991------------ 1,138,530 112,975 - 1,251,505 December 31, 1992------------ 1,168,386(1) 194,366 - 1,362,752 December 31, 1993------------ 1,167,313(1) 250,572 71,393 1,489,278 Liquids (MBbl)(2) December 31, 1990------------ 15,269 6,804 - 22,073 December 31, 1991------------ 13,002 6,484 - 19,486 December 31, 1992------------ 12,762(1) 5,329 - 18,091 December 31, 1993------------ 11,165(1) 5,409 1,591 18,165 (1) Includes approximately 87 billion cubic feet equivalent (96 trillion British thermal units) in 1993 and 114 billion cubic feet equivalent (126 trillion British thermal units) in 1992 associated with a volumetric production payment sold effective October 1, 1992 to be delivered over a seventy-eight month period, as revised, which period commenced October 1, 1992. (2) Includes crude oil, condensate and natural gas liquids.
CAPITALIZED COSTS RELATING TO OIL AND GAS PRODUCING ACTIVITIES. The following table sets forth the capitalized costs relating to the Company's natural gas and crude oil producing activities at December 31, 1993 and 1992: 1993 1992 Proved properties-------------------- $ 2,675,419 $ 2,396,601 Unproved properties------------------ 96,801 78,770 Total---------------------------- 2,772,220 2,475,371 Accumulated depreciation, depletion and amortization------------------- (1,226,175) (1,007,360) Net capitalized costs---------------- $ 1,546,045 1,468,011 COSTS INCURRED IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION AND DEVELOPMENT ACTIVITIES. The acquisition, exploration and development costs disclosed in the following tables are in accordance with definitions in SFAS No. 19 - 'Financial Accounting and Reporting by Oil and Gas Producing Companies'. Acquisition costs include costs incurred to purchase, lease, or otherwise acquire property. Exploration costs include exploration expenses, additions to exploration wells in progress, and depreciation of support equipment used in exploration activities. Development costs include additions to production facilities and equipment, additions to development wells in progress and related facilities, and depreciation of support equipment and related facilities used in development activities. The following tables set forth costs incurred related to the Company's oil and gas activities for the years ended December 31:
FOREIGN UNITED STATES CANADA TRINIDAD OTHER TOTAL 1993 Acquisition Costs of Properties Unproved------------------------- $ 23,686 $ 4,556 $ - $ 887 $ 29,129 Proved--------------------------- 6,625 2,598 - - 9,223 Total------------------------ 30,311 7,154 - 887 38,352 Exploration Costs-------------------- 53,918 9,096 1,367 18,595 82,976 Development Costs-------------------- 247,705 28,045 41,262 - 317,012 Total------------------------ $ 331,934 $ 44,295 $ 42,629 $ 19,482 $ 438,340 (TABLE CONTINUED ON FOLLOWING PAGE) F-23 1992 Acquisition Costs of Properties Unproved------------------------- $ 21,844 $ 1,173 $ - $ 3 $ 23,020 Proved--------------------------- 25,958 39,281 - - 65,239 Total------------------------ 47,802 40,454 - 3 88,259 Exploration Costs-------------------- 38,547 5,787 151 10,990 55,475 Development Costs-------------------- 256,814 5,162 735 - 262,711 Total------------------------ $ 343,163 $ 51,403 $ 886 $ 10,993 $ 406,445 1991 Acquisition Costs of Properties Unproved------------------------- $ 12,156 $ 223 $ - $ 176 $ 12,555 Proved--------------------------- 40,039 2,362 - - 42,401 Total------------------------ 52,195 2,585 - 176 54,956 Exploration Costs-------------------- 39,916 5,369 - 15,062 60,347 Development Costs-------------------- 132,200 10,338 - - 142,538 Total------------------------ $ 224,311 $ 18,292 $ - $ 15,238 $ 257,841
RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES(1). The following tables set forth results of operations for oil and gas producing activities for the years ended December 31:
FOREIGN UNITED STATES CANADA TRINIDAD OTHER TOTAL 1993 Operating Revenues Associated Companies------------- $ 369,824 $ 9,637 $ - $ - $ 379,461 Trade---------------------------- 140,552 33,228 1,209 - 174,989 Total------------------------ 510,376 42,865 1,209 - 554,450 Exploration Expenses, including Dry Hole------------------------------- 35,029 6,657 1,367 12,223 55,276 Production Costs--------------------- 75,767 14,063 1,496 - 91,326 Impairment of Unproved Oil and Gas Properties------------------------- 19,499 968 - - 20,467 Depreciation, Depletion and Amortization----------------------- 234,292 14,630 387 154 249,463 Income (Loss) before Income Taxes---- 145,789 6,547 (2,041) (12,377) 137,918 Income Tax Provision (Benefit)------- (20,329) 2,447 (1,020) (1,742) (20,644) Results of Operations---------------- $ 166,118 $ 4,100 $ (1,021) $ (10,635) $ 158,562 1992 Operating Revenues Associated Companies------------- $ 251,649 $ 10,074 $ - $ - $ 261,723 Trade---------------------------- 106,633 19,313 - - 125,946 Total------------------------ 358,282 29,387 - - 387,669 Exploration Expenses, including Dry Hole------------------------------- 29,705 3,829 151 10,357 44,042 Production Costs--------------------- 63,571 9,271 - - 72,842 Impairment of Unproved Oil and Gas Properties------------------------- 12,001 1,034 - 2,101 15,136 Depreciation, Depletion and Amortization----------------------- 167,767 11,719 - 327 179,813 Income (Loss) before Income Taxes---- 85,238 3,534 (151) (12,785) 75,836 Income Tax Provision (Benefit)------- (16,030) 1,202 (75) (4,323) (19,226) Results of Operations---------------- $ 101,268 $ 2,332 $ (76) $ (8,462) $ 95,062 (TABLE CONTINUED ON FOLLOWING PAGE) F-24 1991 (RESTATED)(2) Operating Revenues Associated Companies------------- $ 197,841 $ 10,244 $ - $ - $ 208,085 Trade---------------------------- 78,964 19,004 - - 97,968 Total------------------------ 276,805 29,248 - - 306,053 Exploration Expenses, including Dry Hole------------------------------- 28,107 3,659 - 14,402 46, 168 Production Costs--------------------- 56,167 9,418 - - 65,585 Impairment of Unproved Oil and Gas Properties------------------------- 10,342 2,449 - - 12,791 Depreciation, Depletion and Amortization----------------------- 148,401 12,385 - 99 160,885 Income (Loss) before Income Taxes---- 33,788 1,337 - (14,501) 20,624 Income Tax Provision (Benefit)------- (5,076) 455 - (4,930) (9,551) Results of Operations---------------- $ 38,864 $ 882 $ - $(9,571) $ 30,175 (1) Excludes net revenues associated with other marketing activities, interest charges, general corporate expenses and certain gathering and handling fees for each of the three years in the period ended December 31, 1993. The gathering and handling fees and other marketing net revenues are directly associated with oil and gas operations with regard to segment reporting as defined in SFAS No. 14 - 'Financial Reporting for Segments of a Business Enterprise', but are not part of Disclosures about Oil and Gas Producing Activities as defined in SFAS No. 69. (2) Effective January 1, 1993, the Company adopted SFAS No. 109 and applied the provisions of the statement retroactively. As a result, the previously reported Income Tax Provision (Benefit) and Results of Operations for 1991 were restated to $9.6 million benefit and $30.2 million, respectively, from $16.6 million benefit and $37.2 million, respectively, a reduction of $7.0 million primarily to recognize the enactment of a change in the computation of certain state franchise taxes, a portion of which is treated as an income tax under SFAS No. 109. The Results of Operations for 1992 and 1993 was not affected by the restatement.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES. The following information has been developed utilizing procedures prescribed by SFAS No. 69 and based on crude oil and natural gas reserve and production volumes estimated by the engineering staff of the Company. It may be useful for certain comparison purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company. The future cash flows presented below are based on sales prices, cost rates, and statutory income tax rates in existence as of the date of the projections. It is expected that material revisions to some estimates of crude oil and natural gas reserves may occur in the future, development and production of the reserves may occur in periods other than those assumed, and actual prices realized and costs incurred may vary significantly from those used. Management does not rely upon the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable as well as proved reserves, and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated. F-25 The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company's crude oil and natural gas reserves at December 31, for the years ended December 31:
1993 UNITED STATES CANADA TRINIDAD TOTAL Future revenues(1)------------------- $ 3,343,900(3) $ 592,845 $ 147,542 $ 4,084,287 Future production costs-------------- (639,760) (230,230) (45,385) (915,375) Future development costs------------- (165,473) (21,001) (7,582) (194,056) Future net cash flows before income taxes------------------------------ 2,538,667 341,614 94,575 2,974,856 Discount to present value at 10% annual rate------------------------ (951,748) (143,992) (20,097) (1,115,837) Present value of future net cash flows before income taxes---------- 1,586,919 197,622 74,478 1,859,019 Future income taxes discounted at 10% annual rate(2)--------------------- (219,228) (37,851) (24,899) (281,978) Standardized measure of discounted future net cash flows relating to proved oil and gas reserves(1)----- $ 1,367,691(4) $ 159,771 $ 49,579 $ 1,577,041 1992 Future revenues(1)------------------- $ 3,017,188(3) $ 363,284 - $ 3,380,472 Future production costs-------------- (573,763) (105,802) - (679,565) Future development costs------------- (194,246) (12,881) - (207,127) Future net cash flows before income taxes------------------------------ 2,249,179 244,601 - 2,493,780 Discount to present value at 10% annual rate------------------------ (790,027) (91,126) - (881,153) Present value of future net cash flows before income taxes---------- 1,459,152 153,475 - 1,612,627 Future income taxes discounted at 10% annual rate(2)--------------------- (147,736) (28,056) - (175,792) Standardized measure of discounted future net cash flows relating to proved oil and gas reserves(1)----- $ 1,311,416(4) $ 125,419 $ - $ 1,436,835 1991 Future revenues(1)------------------- $ 2,501,439 $ 269,917 - $ 2,771,356 Future production costs-------------- (504,420) (79,413) - (583,833) Future development costs------------- (189,091) (6,132) - (195,223) Future net cash flows before income taxes------------------------------ 1,807,928 184,372 - 1,992,300 Discount to present value at 10% annual rate------------------------ (618,919) (62,137) - (681,056) Present value of future net cash flows before income taxes---------- 1,189,009 122,235 - 1,311,244 Future income taxes discounted at 10% annual rate(2)--------------------- (127,188) (27,979) - (155,167) Standardized measure of discounted future net cash flows relating to proved oil and gas reserves(1)----- $ 1,061,821 $ 94,256 $ - $ 1,156,077 (1) Based on year end market prices determined at the point of delivery from the producing unit. (2) Future income taxes before discount were $540.3 million U.S., $91.7 million Canada, $35.5 million Trinidad and $667.5 million total; $394.1 million U.S., $63.0 million Canada and $457.1 million total; and $279.4 million U.S., $53.0 million Canada and $332.4 million total for the years ended December 31, 1993, 1992 and 1991, respectively. (3) 'Future revenues' includes approximately $189.1 million ($146.9 million discounted at 10% annual rate) for 1993 and $203.5 million ($174.5 million discounted at 10% annual rate) for 1992 related to volumes associated with a volumetric production payment sold effective October 1, 1992, as amended, to be delivered over a seventy-eight month period, as revised, which period commenced October 1, 1992. (4) Includes approximately $92.6 million in 1993 and $111.2 million in 1992 representing the discounted present value at a discount rate of 10% of the 'Future revenues' detailed in note (3) after deducting future income taxes.
F-26 CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS. The following table sets forth the changes in the standardized measure of discounted future net cash flows at December 31, for each of the three years in the period ended December 31, 1993.
UNITED STATES CANADA TRINIDAD TOTAL December 31, 1990-------------------- $ 928,584 $ 130,742 $ - $ 1,059,326 Sales and transfers of oil and gas produced, net of production costs--------------------------- (220,638) (19,830) - (240,468) Net changes in prices and production costs---------------- (150,061) (51,609) - (201,670) Extensions, discoveries, additions and improved recovery net of related costs------------------- 212,097 4,802 - 216,899 Development costs incurred-------- 36,719 11 - 36,730 Revisions of estimated development costs--------------------------- 1,640 2,833 - 4,473 Revisions of previous quantity estimates----------------------- 37,535 1,178 - 38,713 Accretion of discount------------- 116,559 17,823 - 134,382 Net change in income taxes-------- 109,821 19,512 - 129,333 Purchases of reserves in place---- 38,350 (558) - 37,792 Sales of reserves in place-------- (17,321) (2,328) - (19,649) Changes in timing and other------- (31,464) (8,320) - (39,784) December 31, 1991-------------------- 1,061,821 94,256 - 1,156,077 Sales and transfers of oil and gas produced, net of production costs--------------------------- (294,711) (20,116) - (314,827) Net changes in prices and production costs---------------- 257,572 8,190 - 265,762 Extensions, discoveries, additions and improved recovery net of related costs------------------- 275,231 8,999 - 284,230 Development costs incurred-------- 49,668 177 - 49,845 Revisions of estimated development costs--------------------------- (19,540) 1,406 - (18,134) Revisions of previous quantity estimates----------------------- (45,863) (7,539) - (53,402) Accretion of discount------------- 118,901 12,224 - 131,125 Net change in income taxes-------- (20,548) (77) - (20,625) Purchases of reserves in place---- 28,884 32,533 - 61,417 Sales of reserves in place-------- (34,984) (15) - (34,999) Changes in timing and other------- (65,015) (4,619) - (69,634) December 31, 1992-------------------- 1,311,416 125,419 - 1,436,835 Sales and transfers of oil and gas produced, net of production costs--------------------------- (434,609) (28,802) 287 (463,124) Net changes in prices and production costs---------------- 180,240 28,400 - 208,640 Extensions, discoveries, additions and improved recovery net of related costs------------------- 275,722 27,785 74,191 377,698 Development costs incurred-------- 58,500 13,900 - 72,400 Revisions of estimated development costs--------------------------- 32,196 (1,345) - 30,851 Revisions of previous quantity estimates----------------------- (26,118) 5,668 - (20,450) Accretion of discount------------- 145,915 15,348 - 161,263 Net change in income taxes-------- (71,492) (9,795) (24,899) (106,186) Purchases of reserves in place---- 9,462 2,707 - 12,169 Sales of reserves in place-------- (38,498) (1,140) - (39,638) Changes in timing and other------- (75,043) (18,374) - (93,417) December 31, 1993-------------------- $ 1,367,691 $ 159,771 $ 49,579 $ 1,577,041
F-27 UNAUDITED QUARTERLY FINANCIAL INFORMATION
QUARTER ENDED MARCH 31 JUNE 30 SEPT. 30 DEC. 31 1993 Net Operating Revenues--------------- $ 136,820 $ 140,493 $ 141,098 $ 149,291 Operating Income--------------------- $ 29,619 $ 31,524 $ 26,902 $ 14,196 Income before Income Taxes----------- $ 28,955 $ 29,598 $ 37,168 $ 16,552 Income Tax Provision (Benefit)------- (1,253) (3,923) 1,412 (21,988) Net Income--------------------------- $ 30,208 $ 33,521 $ 35,756 $ 38,540 Earnings Per Share of Common Stock------------------------------ $ .38 $ .42 $ .45 $ .48 Average Number of Common Shares------ 80,000 80,000 80,000 79,932 1992 Net Operating Revenues--------------- $ 98,630 $ 100,457 $ 111,858 $ 142,044 Operating Income--------------------- $ 20,936 $ 13,822 $ 24,392 $ 40,422 Income before Income Taxes----------- $ 14,079 $ 11,665 $ 18,639 $ 35,461 Income Tax Benefit------------------- (8,208) (2,900) (1,960) (4,668) Net Income--------------------------- $ 22,287 $ 14,565 $ 20,599 $ 40,129 Earnings Per Share of Common Stock------------------------------ $ .29 $ .19 $ .27 $ .50 Average Number of Common Shares------ 75,900 75,900 77,267 80,000 1991 (RESTATED) Net Operating Revenues--------------- $ 95,894 $ 87,971 $ 83,956 $ 119,784 Operating Income--------------------- $ 19,139 $ 12,899 $ 6,050 $ 25,313 Income before Income Taxes----------- $ 11,182 $ 3,562 $ 11,265 $ 19,660 Income Tax Provision (Benefit)------- (705) (3,690) 4,856 (2,708) Net Income--------------------------- $ 11,887 $ 7,252 $ 6,409 $ 22,368 Earnings Per Share of Common Stock------------------------------ $ .16 $ .10 $ .08 $ .29 Average Number of Common Shares------ 75,900 75,900 75,900 75,900
F-28 SCHEDULE V ENRON OIL & GAS COMPANY SCHEDULE V -- PROPERTY, PLANT AND EQUIPMENT FOR THE YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
COLUMN A COLUMN B COLUMN C COLUMN D COLUMN E COLUMN F BALANCE AT OTHER BALANCE AT BEGINNING ADDITIONS CHANGES END CLASSIFICATION OF YEAR AT COST RETIREMENTS ADD (DEDUCT)(A) OF YEAR 1993 Oil and Gas Properties--------------- $ 2,475,371 $ 383,064 $ 55,617 $ (30,598) $ 2,772,220 1992 Oil and Gas Properties--------------- $ 2,228,634 $ 362,403 $ 80,242 $ (35,424) $ 2,475,371 1991 Oil and Gas Properties--------------- $ 2,065,999 $ 211,673 $ 38,339 $ (10,699) $ 2,228,634 (a) Includes, among other things, amortized impairments of unproved oil and gas properties and foreign currency translation adjustments.
S-1 SCHEDULE VI ENRON OIL & GAS COMPANY SCHEDULE VI -- ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION OF PROPERTY, PLANT AND EQUIPMENT FOR THE YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
COLUMN A COLUMN B COLUMN C COLUMN D COLUMN E COLUMN F ADDITIONS BALANCE AT CHARGED TO OTHER BALANCE AT BEGINNING COSTS AND CHANGES END CLASSIFICATION OF YEAR EXPENSES RETIREMENTS ADD (DEDUCT) OF YEAR 1993 Oil and Gas Properties--------------- $ 1,007,360 $ 249,704 $ 26,818 $ (4,071) $ 1,226,175 1992 Oil and Gas Properties--------------- $ 888,968 $ 179,839 $ 52,681 $ (8,766) $ 1,007,360 1991 Oil and Gas Properties--------------- $ 760,863 $ 160,885 $ 30,802 $ (1,978) $ 888,968
S-2 SCHEDULE VIII ENRON OIL & GAS COMPANY SCHEDULE VIII -- VALUATION AND QUALIFYING ACCOUNTS AND RESERVES FOR THE YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS)
COLUMN A COLUMN B COLUMN C COLUMN D COLUMN E ADDITIONS DEDUCTIONS BALANCE AT CHARGED TO FOR PURPOSE FOR BALANCE AT BEGINNING OF COSTS AND WHICH RESERVES END OF DESCRIPTION YEAR EXPENSES WERE CREATED YEAR 1993 Reserves deducted from assets to which they apply - Revaluation of Accounts Receivable--------------------- $ - $ 1,020 $ - $ 1,020 Litigation Reserve(a)---------------- $ 2,030 $ 2,520 $ 2,550 $ 2,000 1992 Reserves deducted from assets to which they apply - Revaluation of Accounts Receivable--------------------- $ 5,656 $ 600 $ 6,256 $ - Litigation Reserve(a)---------------- $ 1,082 $ 2,194 $ 1,246 $ 2,030 1991 Reserves deducted from assets to which they apply - Revaluation of Accounts Receivable--------------------- $ 4,796 $ 2,600 $ 1,740 $ 5,656 Litigation Reserve(a)---------------- $ 1,400 $ 1,200 $ 1,518 $ 1,082 (a) Included in Other Liabilities on the consolidated balance sheets.
S-3 SCHEDULE X ENRON OIL & GAS COMPANY SCHEDULE X -- SUPPLEMENTAL INCOME STATEMENT INFORMATION FOR THE YEARS ENDED DECEMBER 31, 1993, 1992 AND 1991 (IN THOUSANDS) COLUMN A COLUMN B CHARGED TO EXPENSES ITEM 1993 1992 1991 Maintenance and repairs-------------- $ 8,198 $ 7,169 $ 7,107 Taxes, other than payroll and income taxes Property-------------------------- $ 12,525 $ 11,488 $ 6,401 Production/Severance-------------- 19,578 11,985 9,262 Franchise------------------------- 563 2,788 575 Other----------------------------- 107 32 124 Total-------------------------- $ 32,773 $ 26,293 $ 16,362 S-4 EXHIBITS Exhibits not incorporated herein by reference to a prior filing are designated by an asterisk (*) and are filed herewith; all exhibits not so designated are incorporated herein by reference to the Company's Form S-1 Registration Statement, Registration No. 33-30678, filed on August 24, 1989 ('Form S-1'), or as otherwise indicated. 3.1(a) - Restated Certificate of Incorporation of Enron Oil & Gas Company (Exhibit 3.1 to Form S-1). 3.1(b) - Certificate of Amendment of Restated Certificate of Incorporation of Enron Oil & Gas Company (Exhibit 4.1(b) to Form S-8 Registration Statement, Registration No. 33-52201, filed on February 8, 1994). 3.2* - Bylaws of Enron Oil & Gas Company. 3.3 - Specimen of Certificate evidencing the Common Stock (Exhibit 3.3 to Form S-1). 4.1 - Promissory Note due May 1, 1996, dated May 1, 1991 (Exhibit 4.1 to the Company's Annual Report on Form 10-K for the year ended December 31, 1991). 4.2 - There have not been filed as exhibits to this Form 10-K debt instruments defining the rights of holders of long-term debt of the Company, none of which relates to authorized indebtedness that exceeds 10% of the consolidated assets of the Company and its subsidiaries. The Company hereby agrees to furnish a copy of any such instrument to the Commission upon request. 4.3 - Enron Oil & Gas Company 1994 Stock Plan (Exhibit 4.1(b) to Form S-8 Registration Statement No. 33-52201, filed on February 8, 1994). 10.1* - Services Agreement, dated as of January 1, 1994, between Enron Oil & Gas Company and Enron Corp. 10.2 - Stock Restriction and Registration Agreement dated as of August 23, 1989 (Exhibit 10.2 to Form S-1). 10.3 - Tax Allocation Agreement dated as of August 23, 1989 (Exhibit 10.3 to Form S-1), and First Amended and Restated Tax Allocation Agreement dated as of August 9, 1991, as amended on February 6, 1992 (Exhibit 10.3 to Form S-1 Registration Statement, Registration No. 33-50462, filed on August 5, 1992). 10.4 - Enron Corp. Deferral Plan dated December 10, 1985 (Exhibit 10.12 to Form S-1). 10.5 - Enron Corp. 1988 Stock Plan (Exhibit 10.13 to Form S-1). 10.6 - Enron Oil & Gas Company Key Contributor Incentive Plan (Exhibit 10.6 to the Company's Annual Report on Form 10-K for the year ended December 31, 1990). 10.7 - Enron Corp. 1984 Stock Option Plan (Exhibit 10.15 to Form S-1). 10.8 - Enron Corp. 1986 Stock Option Plan (Exhibit 10.16 to Form S-1). 10.9 - Employment Agreement between Enron Oil & Gas Company and Forrest Hoglund, dated as of September 1, 1987, as amended (Exhibit 10.19 to Form S-1), and Second and Third Amendments to Employment Agreement dated June 30, 1989 and February 14, 1992, respectively (Exhibit 10.10 to Form S-1 Registration Statement, Registration No. 33-50462, filed on August 5, 1992). 10.10 - Fuel Supply Contract, dated as of June 30, 1986, by and between Enron Oil & Gas Company, HNG Oil Company, BelNorth Petroleum Corporation and Enron Cogenration One Company, as amended (Exhibit 10.23 to Form S-1). 10.11 - Gas Sales Contract dated September 2, 1987 between Enron Oil & Gas Com- pany and Cogenron Inc., as amended (Exhibit 10.24 to Form S-1). E-1 10.12 - Letter Agreement dated August 20, 1987 between Enron Oil & Gas Company and Panhandle Gas Company (Exhibit 10.25 to Form S-1). 10.13 - Pension Program for Enron Corp. Deferral Plan Participants, effective January 1, 1985, as amended (Exhibit 10.29 to Form S-1). 10.14 - Enron Oil & Gas Company 1993 Nonemployee Director Stock Option Plan (Exhibit 10.14 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.15* - Credit Agreement, dated as of March 11, 1994, among Enron Oil & Gas Company, the Banks named therein and Texas Commerce Bank, National Association, as Administrative Agent and Promissory Note due January 15, 1998, dated March 11, 1994 to the order of Texas Commerce Bank National Association, Promissory Note due January 15, 1998, dated March 11, 1994 to the order of The Bank of New York, Promissory Note due January 15, 1998, dated March 11, 1994 to the order of The Bank of Nova Scotia, Promissory Note due January 15, 1998, dated March 11, 1994 to the order of Credit Lyonnais Cayman Islands Branch, Promissory Note due January 15, 1998, dated March 11, 1994 to the order of Credit Suisse, Promissory Note due January 15, 1998, dated March 11, 1994 to the order of The First National Bank of Chicago, and Promissory Note due January 15, 1998, dated March 11, 1994 to the order of Bank of America National Trust and Savings Association. 10.16* - Interest Rate and Currency Exchange Agreement, dated as of June 1, 1991, between Enron Risk Management Services Corp. and Enron Oil & Gas Market- ing, Inc. (Exhibit 10.17 to the Company's Annual Report on Form 10-K for the year ended December 31, 1991), Confirmation dated June 14, 1992 (Exhibit 10.17 to Form S-1 Registration Statement, Registration No. 33-50462, filed on August 5, 1992) and Confirmations dated March 25, 1991, April 25, 1991, and September 23, 1992 (assigned to Enron Risk Management Services Corp. by Enron Finance Corp. pursuant to an Assignment and Assumption Agreement, dated as of November 1, 1993, by and between Enron Finance Corp., Enron Risk Management Services Corp. and Enron Oil & Gas Marketing, Inc.). 10.17* - Assignment and Assumption Agreement, dated as of November 1, 1993, by and between Enron Oil & Gas Marketing, Inc., Enron Oil & Gas Company and Enron Risk Management Services Corp. 10.18* - ISDA Master Agreement, dated as of November 1, 1993, between Enron Oil & Gas Company and Enron Risk Management Services Corp., and Confirmation Nos. 1268.0, 1286.0, 1291.0, 1292.0, 1304.0, 1305.0, 1321.0, 1335.0, 1338.0, 1370.0, 1471.0, 1485.0, 1486.0, 1494.0, 1495.0, 1509.0, 1514.0, 1533.01, 1569.0, 1986.0, 2217.0, 2227.0, 2278.0, 2299.0, 2372.0, 2647.0. 10.19 - Letter Agreement between Colorado Interstate Gas Company and Enron Oil & Gas Marketing, Inc. dated November 1, 1990 (Exhibit 10.18 to the Company's Annual Report on Form 10-K for the year ended December 31, 1990). 10.20 - Gathering Agreement between Enron Oil & Gas Company and Northwest Pipeline Corporation dated March 30, 1989, as amended (Exhibit 10.36 to Form S-1). 10.21 - Processing Agreement between Enron Oil & Gas Company and Northwest Pipeline Corporation dated March 30, 1989 (Exhibit 10.37 to Form S-1). 10.22 - Gas Sales Agreement between Enron Gas Marketing, Inc. and Enron Oil & Gas Marketing, Inc. dated August 22, 1989 (Exhibit 10.38 to Form S-1). 10.23 - Gas Purchase Agreement between Enron Oil & Gas Company and Enron Oil & Gas Marketing, Inc. dated August 22, 1989 (Exhibit 10.41 to Form S-1). 10.24 - Gas Purchase Agreement between Enron Oil & Gas Company and Enron Oil & Gas Marketing, Inc. dated August 22, 1989 (Exhibit 10.42 to Form S-1). 10.25 - Enron Corp. 1991 Stock Plan (Exhibit 10.08 to Enron Corp. Annual Report on Form 10-K for the year ended December 31, 1991). 10.26 - Enron Corp. 1988 Deferral Plan (Exhibit 10.49 to Form S-1). E-2 10.27 - Form of Enron Corp. Long-Term Incentive Plan Effective as of January 1, 1987 (Exhibit 10.50 to Form S-1). 10.28 - Enron Executive Supplemental Survivor Benefits Plan Effective January 1, 1987 (Exhibit 10.51 to Form S-1). 10.29 - 1988 FlexPerq Program Summary (Exhibit 10.52 to Form S-1). 10.30 - Credit Agreement between Enron Corp. and Enron Oil & Gas Company dated September 29, 1992 (Exhibit 10.28 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.31 - Credit Agreement between Enron Oil & Gas Company and Enron Corp. dated September 29, 1992 (Exhibit 10.29 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.33 - Swap Agreement between Banque Paribas and Enron Oil & Gas Company, dated as of December 5, 1990 (Exhibit 10.37 to the Company's Annual Report on Form 10-K for the year ended December 31, 1990), and Confirmations dated March 25, 1991 and April 25, 1991 (Exhibit 10.37 to Form S-1 Registration Statement, Registration No. 33-50462, filed on August 5, 1992). 10.34 - Enron Oil & Gas Company 1992 Stock Plan (Exhibit 10.40 to the Company's Annual Report on Form 10-K for the year ended December 31, 1991). 10.35 - Enron Corp. 1992 Deferral Plan (Exhibit 10.41 to the Company's Annual Report on Form 10-K for the year ended December 31, 1991). 10.36(a) - Conveyance of Production Payment, dated September 25, 1992, between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit 10.34 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.36(b)* - First Amendment to Conveyance of Production Payment, dated effective April 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.36(c)* - Second Amendment to Conveyance of Production Payment, dated effective July 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.36(d)* - Third Amendment to Conveyance of Production Payment, dated effective October 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.37* - Fourth Amendment to Hydrocarbon Exchange Agreement, dated effective October 1, 1993, between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.38 - Purchase and Sale Agreement, dated September 25, 1992, between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit 10.36 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.39(a) - Production and Delivery Agreement, dated September 25, 1992, between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit 10.37 to the Company's Annual Report on Form 10-K for the year ended December 31, 1992). 10.39(b)* - First Amendment to Production and Delivery Agreement, dated effective April 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.39(c)* - Second Amendment to Production and Delivery Agreement, dated effective July 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. E-3 10.39(d)* - Third Amendment to Production and Delivery Agreement, dated effective October 1, 1993 between Enron Oil & Gas Company and Cactus Hydrocarbon 1992-A Limited Partnership. 10.40* - Credit Agreement, dated as of March 8, 1994 between Enron Gas & Oil Trinidad Limited and Caribbean Regional Development Investment Trust, and Request for Advance No. 1, dated March 4, 1993, and Request for Advance No. 2, dated March 4, 1993. 10.41* - Promissory Note due May 1, 1998, dated as of March 8, 1994, to the order of Caribbean Regional Development Investment Trust. 10.42* - Promissory Note due May 1, 1998, dated as of March 8, 1994 to the order of Caribbean Regional Development Investment Trust. 10.43* - Letter of Credit and Reimbursement Agreement, dated March 8, 1994, between Enron Gas & Oil Trinidad Limited and Credit Suisse. 10.44* - Parent Guaranty, dated March 8, 1994 between Enron Oil & Gas Company and Credit Suisse. 22* - List of subsidiaries. 23.1* - Consent of DeGolyer and MacNaughton. 23.2* - Opinion of DeGolyer and MacNaughton dated January 27, 1994. 24* - Powers of Attorney.
E-4 SIGNATURES PURSUANT TO THE REQUIREMENTS OF SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934, THE REGISTRANT HAS DULY CAUSED THIS REPORT TO BE SIGNED ON ITS BEHALF BY THE UNDERSIGNED, THEREUNTO DULY AUTHORIZED, ON THE 18TH DAY OF MARCH, 1994. ENRON OIL & GAS COMPANY (REGISTRANT) By /s/ WALTER C. WILSON (WALTER C. WILSON) SENIOR VICE PRESIDENT AND CHIEF FINANCIAL OFFICER PURSUANT TO THE REQUIREMENTS OF THE SECURITIES EXCHANGE ACT OF 1934, THIS REPORT HAS BEEN SIGNED BY THE FOLLOWING PERSONS ON BEHALF OF REGISTRANT AND IN THE CAPACITIES WITH ENRON OIL & GAS COMPANY INDICATED AND ON THE 18TH DAY OF MARCH, 1994. SIGNATURE TITLE /s/ FORREST E. HOGLUND Chairman of the Board, President and (FORREST E. HOGLUND) Chief Executive Officer and Director (Principal Executive Officer) /s/ WALTER C. WILSON Senior Vice President and Chief (WALTER C. WILSON) Financial Officer (Principal Financial Officer) /s/ BEN B. BOYD Vice President and Controller (BEN B. BOYD) (Principal Accounting Officer) FRED C. ACKMAN * Director (FRED C. ACKMAN) RICHARD D. KINDER * Director (RICHARD D. KINDER) KENNETH L. LAY * Director (KENNETH L. LAY) EDWARD RANDALL, III * Director (EDWARD RANDALL, III) *By /s/ ANGUS H. DAVIS (ANGUS H. DAVIS) (ATTORNEY-IN-FACT FOR PERSONS INDICATED) EX-3.2 2 BYLAWS EXHIBIT 3.2 BYLAWS OF ENRON OIL & GAS COMPANY A Delaware Corporation Date of Adoption August 23, 1989 As Amended December 12, 1990 and February 8, 1994 BYLAWS Table of Contents PAGE Article I. OFFICES Section 1. Registered Office 1 Section 2. Other Offices 1 Article II. STOCKHOLDERS Section 1. Place of Meetings 1 Section 2. Quorum; Adjournment of Meetings 1 Section 3. Annual Meetings 2 Section 4. Special Meetings 2 Section 5. Record Date 3 Section 6. Notice of Meeting 3 Section 7. Stockholder List 3 Section 8. Proxies 4 Section 9. Voting; Elections; Inspectors 4 Section 10. Conduct of Meetings 5 Section 11. Treasury Stock 5 Section 12. Business to Be Brought Before the Annual Meeting 5 Article III. BOARD OF DIRECTORS Section 1. Power; Number; Term of Office 7 Section 2. Quorum; Voting 7 Section 3. Place of Meetings; Order of Business 7 Section 4. First Meeting 7 Section 5. Regular Meetings 8 Section 6. Special Meetings 8 Section 7. Nomination of Directors 8 Section 8. Removal 9 Section 9. Vacancies; Increases in the Number of Directors 9 Section 10. Compensation 10 Section 11. Action Without a Meeting; Telephone Conference Meeting 10 Section 12. Approval or Ratification of Acts or Contracts by Stockholders 10 PAGE Article IV. COMMITTEES Section 1. Executive Committee 10 Section 2. Audit Committee 11 Section 3. Other Committees 11 Section 4. Procedure; Meetings; Quorum 11 Section 5. Substitution and Removal of Members; Vacancies 12 Article V. OFFICERS Section 1. Number, Titles and Term of Office 12 Section 2. Powers and Duties of the Chairman of the Board 12 Section 3. Powers and Duties of the President, President-North American Operations, and President-International Operations 13 Section 4. Powers and Duties of Vice Chairman of the Board 13 Section 5. Vice Presidents 14 Section 6. General Counsel 14 Section 7. Secretary 14 Section 8. Deputy Corporate Secretary and Assistant Secretaries 14 Section 9. Treasurer 15 Section 10. Assistant Treasurers 15 Section 11. Action with Respect to Securities of Other Corporations 15 Section 12. Delegation 15 Article VI. CAPITAL STOCK Section 1. Certificates of Stock 16 Section 2. Transfer of Shares 16 Section 3. Ownership of Shares 16 Section 4. Regulations Regarding Certificates 17 Section 5. Lost or Destroyed Certificates 17 PAGE Article VII. MISCELLANEOUS PROVISIONS Section 1. Fiscal year 17 Section 2. Corporate Seal 17 Section 3. Notice and Waiver of Notice 17 Section 4. Facsimile Signatures 18 Section 5. Reliance upon Books, Reports and Records 18 Section 6. Application of Bylaws 18 Article VIII. AMENDMENTS 19 BYLAWS OF ENRON OIL & GAS COMPANY Article I OFFICES SECTION 1. REGISTERED OFFICE. The registered office of the Corporation required by the General Corporation Law of the State of Delaware to be maintained in the State of Delaware shall be the registered office named in the original Certificate of Incorporation of the Corporation, or such other office as may be designated from time to time by the Board of Directors in the manner provided by law. SECTION 2. OFFICES. The Corporation may also have offices at such other places both within and without the state of incorporation of the Corporation as the Board of Directors may from time to time determine or the business of the Corporation may require. Article II STOCKHOLDERS Section 1. PLACE OF MEETINGS. ALL MEETINGS of the stockholders shall be held at the principal office of the Corporation, or at such other place within or without the state of incorporation of the Corporation as shall be specified or fixed in the notices or waivers of notice thereof. SECTION 2. QUORUM; ADJOURNMENT OF MEETINGS. Unless otherwise required by law or provided in the Certificate of Incorporation or these Bylaws, (i) the holders of a majority of the stock issued and outstanding and entitled to vote thereat, present in person or represented by proxy, shall constitute a quorum at any meeting of stockholders for the transaction of business, (ii) in all matters other than election of directors, the affirmative vote of the holders of a majority of such stock so present or represented at any meeting of stockholders at which a quorum is present shall constitute the act of the stockholders, and (iii) where a separate vote by a class or classes is required, a majority of the outstanding shares of such class or classes, present in person or represented by proxy shall constitute a quorum entitled to take action with respect to that vote on that matter and the affirmative vote of the -1- majority of the shares of such class or classes present in person or represented by proxy at the meeting shall be the act of such class. The stockholders present at a duly organized meeting may continue to transact business until adjournment, notwithstanding the withdrawal of enough stockholders to leave less than a quorum, subject to the provisions of clauses (ii) and (iii) above. Directors shall be elected by a plurality of the votes of the shares present in person or represented by proxy at the meeting and entitled to vote on the election of directors. Notwithstanding the other provisions of the Certificate of Incorporation or these Bylaws, the chairman of the meeting or the holders of a majority of the issued and outstanding stock, present in person or represented by proxy and entitled to vote thereat, at any meeting of stockholders, whether or not a quorum is present, shall have the power to adjourn such meeting from time to time, without any notice other than announcement at the meeting of the time and place of the holding of the adjourned meeting. If the adjournment is for more than thirty (30) days, or if after the adjournment a new record date is fixed for the adjourned meeting, a notice of the adjourned meeting shall be given to each stockholder of record entitled to vote at such meeting. At such adjourned meeting at which a quorum shall be present or represented any business may be transacted which might have been transacted at the meeting as originally called. SECTION 3. ANNUAL MEETINGS. An annual meeting of the stockholders, for the election of directors to succeed those whose terms expire and for the transaction of such other business as may properly come before the meeting, shall be held at such place (within or without the state of incorporation of the Corporation), on such date, and at such time as the Board of Directors shall fix and set forth in the notice of the meeting, which date shall be within thirteen (13) months subsequent to the last annual meeting of stockholders. SECTION 4. SPECIAL MEETINGS. Unless otherwise provided in the Certificate of Incorporation, special meetings of the stockholders for any purpose or purposes may be called at any time by the Chairman of the Board, by the President, by the Vice Chairman of the Board, by a majority of the Board of Directors, or by a majority of the executive committee (if any), at such time and at such place as may be stated in the notice of the meeting. A special meeting of stockholders shall be called by the Chairman of the Board, the President or the Secretary upon written request therefor, stating the purpose(s) of the meeting, delivered to such officer and signed by the holder(s) of at least ten percent (10%) of the issued and outstanding stock entitled to vote at such meeting. Business transacted at a special meeting shall be confined to the purpose(s) stated in the notice of such meeting. -2- SECTION 5. RECORD DATE. For the purpose of determining stockholders entitled to notice of or to vote at any meeting of stockholders, or any adjournment thereof, or entitled to receive payment of any dividend or other distribution or allotment of any rights, or entitled to exercise any rights in respect of any change, conversion or exchange of stock or for the purpose of any other lawful action, the Board of Directors of the Corporation may fix a date as the record date for any such determination of stockholders, which record date shall not precede the date on which the resolutions fixing the record date are adopted and which record date shall not be more than sixty (60) days nor less than ten (10) days before the date of such meeting of stockholders, nor more than sixty (60) days prior to any other action. If the Board of Directors does not fix a record date for any meeting of the stockholders, the record date for determining stockholders entitled to notice of or to vote at such meeting shall be at the close of business on the day next preceding the day on which notice is given, or, if in accordance with Article VII, Section 3 of these Bylaws notice is waived, at the close of business on the day next preceding the day on which the meeting is held. The record date for determining stockholders for any other purpose shall be at the close of business on the day on which the Board of Directors adopts the resolution relating thereto. A determination of stockholders of record entitled to notice of or to vote at a meeting of stockholders shall apply to any adjournment of the meeting; provided, however, that the Board of Directors may fix a new record date for the adjourned meeting. SECTION 6. NOTICE OF MEETINGS. Written notice of the place, date and hour of all meetings, and, in case of a special meeting, the purpose or purposes for which the meeting is called, shall be given by or at the direction of the Chairman of the Board, the President, the Vice Chairman of the Board, the Secretary or the other person(s) calling the meeting to each stockholder entitled to vote thereat not less than ten (10) nor more than sixty (60) days before the date of the meeting. Such notice may be delivered either personally or by mail. If mailed, notice is given when deposited in the United States mail, postage prepaid, directed to the stockholder at such stockholder's address as it appears on the records of the Corporation. SECTION 7. STOCKHOLDER LIST. A complete list of stockholders entitled to vote at any meeting of stockholders, arranged in alphabetical order for each class of stock and showing the address of each such stockholder and the number of shares registered in the name of such stockholder, shall be open to the examination of any stockholder, for any purpose germane to the meeting, during ordinary business hours, for a period of at least ten (10) days prior to the meeting, either at a place within the city where the meeting is to be held, which place shall be specified in the notice of the meeting, or if not so specified, at the place where the meeting is to be held. The stockholder list shall also be produced and kept at the time and place of the meeting -3- during the whole time thereof, and may be inspected by any stockholder who is present. SECTION 8. PROXIES. Each stockholder entitled to vote at a meeting of stockholders may authorize another person or persons to act for him by proxy. Proxies for use at any meeting of stockholders shall be filed with the Secretary, or such other officer as the Board of Directors may from time to time determine by resolution, before or at the time of the meeting. All proxies shall be received and taken charge of and all ballots shall be received and canvassed by the secretary of the meeting, who shall decide all questions touching upon the qualification of voters, the validity of the proxies, and the acceptance or rejection of votes, unless an inspector or inspectors shall have been appointed by the chairman of the meeting, in which event such inspector or inspectors shall decide all such questions. No proxy shall be valid after three (3) years from its date, unless the proxy provides for a longer period. Each proxy shall be revocable unless expressly provided therein to be irrevocable and coupled with an interest sufficient in law to support an irrevocable power. Should a proxy designate two or more persons to act as proxies, unless such instrument shall provide the contrary, a majority of such persons present at any meeting at which their powers thereunder are to be exercised shall have and may exercise all the powers of voting or giving consents thereby conferred, or if only one be present, then such powers may be exercised by that one; or, if an even number attend and a majority do not agree on any particular issue, each proxy so attending shall be entitled to exercise such powers in respect of such portion of the shares as is equal to the reciprocal of the fraction equal to the number of proxies representing such shares divided by the total number of shares represented by such proxies. SECTION 9. VOTING; ELECTIONS; INSPECTORS. Unless otherwise required by law or provided in the Certificate of Incorporation, each stockholder shall on each matter submitted to a vote at a meeting of stockholders have one vote for each share of stock entitled to vote which is registered in his name on the record date for the meeting. For the purposes hereof, each election to fill a directorship shall constitute a separate matter. Shares registered in the name of another corporation, domestic or foreign, may be voted by such officer, agent or proxy as the bylaws (or comparable instrument) of such corporation may prescribe, or in the absence of such provision, as the Board of Directors (or comparable body) of such corporation may determine. Shares registered in the name of a deceased person may be voted by the executor or administrator of such person's estate, either in person or by proxy. All voting, except as required by the Certificate of Incorporation or where otherwise required by law, may be by a voice vote; provided, however, upon request of the chairman of the -4- meeting or upon demand therefor by stockholders holding a majority of the issued and outstanding stock present in person or by proxy at any meeting a stock vote shall be taken. Every stock vote shall be taken by written ballots, each of which shall state the name of the stockholder or proxy voting and such other information as may be required under the procedure established for the meeting. All elections of directors shall be by written ballots, unless otherwise provided in the Certificate of Incorporation. At any meeting at which a vote is taken by written ballots, the chairman of the meeting may appoint one or more inspectors, each of whom shall subscribe an oath or affirmation to execute faithfully the duties of inspector at such meeting with strict impartiality and according to the best of such inspector's ability. Such inspector shall receive the written ballots, count the votes and make and sign a certificate of the result thereof. The chairman of the meeting may appoint any person to serve as inspector, except no candidate for the office of director shall be appointed as an inspector. Unless otherwise provided in the Certificate of Incorporation, cumulative voting for the election of directors shall be prohibited. SECTION 10. CONDUCT OF MEETINGS. The meetings of the stockholders shall be presided over by the Chairman of the Board, or if the Chairman of the Board is not present, by the President, or if the President is not present, by the Vice Chairman of the Board, or if neither the Chairman of the Board, the President nor the Vice Chairman of the Board is present, by a chairman elected at the meeting. The Secretary of the Corporation, if present, shall act as secretary of such meetings, or if the Secretary is not present, the Deputy Corporate Secretary or an Assistant Secretary shall so act; if neither the Secretary or the Deputy Corporate Secretary or an Assistant Secretary is present, then a secretary shall be appointed by the chairman of the meeting. The chairman of any meeting of stockholders shall determine the order of business and the procedure at the meeting, including such regulation of the manner of voting and the conduct of discussion as seem to the chairman in order. SECTION 11. TREASURY STOCK. The Corporation shall not vote, directly or indirectly, shares of its own stock owned by it and such shares shall not be counted for quorum purposes. Nothing in this Section 11 shall be construed as limiting the right of the Corporation to vote stock, including but not limited to its own stock, held by it in a fiduciary capacity. SECTION 12. BUSINESS TO BE BROUGHT BEFORE THE ANNUAL MEETING. To be properly brought before the annual meeting of stockholders, business must be either (a) specified in the notice of meeting (or any supplement thereto) given by or at the -5- direction of the Board of Directors, (b) otherwise brought before the meeting by or at the direction of the Board of Directors, or (c) otherwise properly brought before the meeting by a stockholder of the Corporation who is a stockholder of record at the time of giving of notice provided for in this Section 12 of Article II, who shall be entitled to vote at such meeting and who complies with the notice procedures set forth in this Section 12 of Article II. In addition to any other applicable requirements, for business to be brought before an annual meeting by a stockholder of the Corporation, the stockholder must have given timely notice thereof in writing to the Secretary of the Corporation. To be timely, a stockholder's notice must be delivered to or mailed and received at the principal executive offices of the Corporation not less than 90 days prior to the anniversary date of the immediately preceding annual meeting of stockholders of the Corporation. A stockholder's notice to the Secretary shall set forth as to each matter the stockholder proposes to bring before the annual meeting (i) a brief description of the business desired to be brought before the annual meeting and the reasons for conducting such business at the annual meeting, (ii) the name and address, as they appear on the Corporation's books, of the stockholder proposing such business, (iii) the acquisition date, the class and the number of shares of voting stock of the Corporation which are owned beneficially by the stockholder, (iv) any material interest of the stockholder in such business, and (v) a representation that the stockholder intends to appear in person or by proxy at the meeting to bring the proposed business before the meeting. Notwithstanding anything in these Bylaws to the contrary, no business shall be conducted at the annual meeting except in accordance with the procedures set forth in this Section 12. The chairman of the annual meeting shall, if the facts warrant, determine and declare to the meeting that business was not properly brought before the meeting in accordance with the provisions of this Section 12 of Article II, and if the chairman should so determine, the chairman shall so declare to the meeting and any such business not properly brought before the meeting shall not be transacted. Notwithstanding the foregoing provisions of this Section 12 of Article II, a stockholder shall also comply with all applicable requirements of the Securities Exchange Act of 1934, as amended, and the rules and regulations thereunder with respect to the matters set forth in this Section 12. -6- Article III BOARD OF DIRECTORS SECTION 1. POWER; NUMBER; TERM OF OFFICE. The business and affairs of the Corporation shall be managed by or under the direction of the Board of Directors, and subject to the restrictions imposed by law or the Certificate of Incorporation, the Board of Directors may exercise all the powers of the Corporation. The number of directors which shall constitute the whole Board of Directors shall be determined from time to time by the Board of Directors (provided that no decrease in the number of directors which would have the effect of shortening the term of an incumbent director may be made by the Board of Directors). If the Board of Directors makes no such determination, the number of directors shall be three. Each director shall hold office for the term for which such director is elected, and until such Director's successor shall have been elected and qualified or until such Director's earlier death, resignation or removal. Unless otherwise provided in the Certificate of Incorporation, directors need not be stockholders nor residents of the state of incorporation of the Corporation. SECTION 2. QUORUM; VOTING. Unless otherwise provided in the Certificate of Incorporation, a majority of the total number of directors shall constitute a quorum for the transaction of business of the Board of Directors and the vote of a majority of the directors present at a meeting at which a quorum is present shall be the act of the Board of Directors. SECTION 3. PLACE OF MEETINGS; ORDER OF BUSINESS. The directors may hold their meetings and may have an office and keep the books of the Corporation, except as otherwise provided by law, in such place or places, within or without the state of incorporation of the Corporation, as the Board of Directors may from time to time determine. At all meetings of the Board of Directors business shall be transacted in such order as shall from time to time be determined by the Chairman of the Board, or in the Chairman of the Board's absence by the President (should the President be a director), or in the President's absence by the Vice Chairman of the Board, or by the Board of Directors. SECTION 4. FIRST MEETING. Each newly elected Board of Directors may hold its first meeting for the purpose of organization and the transaction of business, if a quorum is present, immediately after and at the same place as the annual meeting of the stockholders. Notice of such meeting shall not be required. At the first meeting of the Board of Directors in each year at which a quorum shall be present, held next after the -7- annual meeting of stockholders, the Board of Directors shall elect the officers of the Corporation. SECTION 5. REGULAR MEETINGS. Regular meetings of the Board of Directors shall be held at such times and places as shall be designated from time to time by the Chairman of the Board or, in the absence of the Chairman of the Board, by the President (should the President be a director), or in the President's absence, by the Vice Chairman of the Board. Notice of such regular meetings shall not be required. SECTION 6. SPECIAL MEETINGS. Special meetings of the Board of Directors may be called by the Chairman of the Board, the President (should the President be a director) or the Vice Chairman of the Board or, on the written request of any two directors, by the Secretary, in each case on at least twenty-four (24) hours personal, written, telegraphic, cable or wireless notice to each director. Such notice, or any waiver thereof pursuant to Article VII, Section 3 hereof, need not state the purpose or purposes of such meeting, except as may otherwise be required by law or provided for in the Certificate of Incorporation or these Bylaws. Meetings may be held at any time without notice if all the directors are present or if those not present waive notice of the meeting in writing. SECTION 7. NOMINATION OF DIRECTORS. Only persons who are nominated in accordance with the following procedures shall be eligible for election as directors. Nominations of persons for election to the Board of Directors of the Corporation may be made at a meeting of stockholders (a) by or at the direction of the Board of Directors or (b) by any stockholder of the Corporation who is a stockholder of record at the time of giving of notice provided for in this Section 7 of Article III, who shall be entitled to vote for the election of directors at the meeting and who complies with the notice procedures set forth in this Section 7 of Article III. Such nominations, other than those made by or at the direction of the Board of Directors, shall be made pursuant to timely notice in writing to the Secretary of the Corporation. To be timely, a stockholder's notice shall be delivered to or mailed and received at the principal executive offices of the Corporation (i) with respect to an election to be held at the annual meeting of the stockholders of the Corporation, 90 days prior to the anniversary date of the immediately preceding annual meeting of stockholders of the Corporation, and (ii) with respect to an election to be held at a special meeting of stockholders of the Corporation for the election of directors, not later than the close of business on the 10th day following the day on which such notice of the date of the meeting was mailed or public disclosure of the date of the meeting was made, whichever first occurs. Such stockholder's notice to the Secretary shall set forth (a) as to each person whom the stockholder proposes to nominate for election or re-election as a director, all information relating to the person that is required to be disclosed in solicitations for proxies for election of directors, or is otherwise required, pursuant to Regulation 14A under the -8- Securities Exchange Act of 1934, as amended (including the written consent of such person to be named in the proxy statement as a nominee and to serve as a director if elected); and (b) as to the stockholder giving the notice (i) the name and address, as they appear on the Corporation's books, of such stockholder, and (ii) the class and number of shares of capital stock of the Corporation which are beneficially owned by the stockholder. At the request of the Board of Directors, any person nominated by the Board of Directors for election as a director shall furnish to the Secretary of the Corporation that information required to be set forth in a stockholder's notice of nomination which pertains to the nominee. In the event that a person is validly designated as nominee to the Board and shall thereafter become unable or unwilling to stand for election to the Board of Directors, the Board of Directors or the stockholder who proposed such nominee, as the case may be, may designate a substitute nominee. No person shall be eligible to serve as a director of the Corporation unless nominated in accordance with the procedures set forth in this Section 7 of Article III. The chairman of the meeting of stockholders shall, if the facts warrant, determine and declare to the meeting that a nomination was not made in accordance with the procedures prescribed by the Bylaws, and if the chairman should so determine, the chairman shall so declare to the meeting and the defective nomination shall be disregarded. Notwithstanding the foregoing provisions of this Section 7 of Article III, a stockholder shall also comply with all applicable requirements of the Securities Exchange Act of 1934, as amended, and the rules and regulations thereunder with respect to the matters set forth in this Section 7 of Article III. SECTION 8. REMOVAL. Any director or the entire Board of Directors may be removed, with or without cause, by the holders of a majority of the shares then entitled to vote at an election of directors. SECTION 9. VACANCIES; INCREASES IN THE NUMBER OF DIRECTORS. Unless otherwise provided in the Certificate of Incorporation, vacancies existing on the Board of Directors for any reason and newly created directorships resulting from any increase in the authorized number of directors may be filled by the affirmative vote of a majority of the directors then in office, although less than a quorum, or by a sole remaining director; and any director so chosen shall hold office until the next annual election and until such Director's successor shall have been elected and qualified, or until such Director's earlier death, resignation or removal. -9- SECTION 10. COMPENSATION. Directors and members of standing committees may receive such compensation as the Board of Directors from time to time shall determine to be appropriate, and shall be reimbursed for all reasonable expenses incurred in attending and returning from meetings of the Board of Directors. SECTION 11. ACTION WITHOUT A MEETING; TELEPHONE CONFERENCE MEETING. Unless otherwise restricted by the Certificate of Incorporation, any action required or permitted to be taken at any meeting of the Board of Directors, or any committee designated by the Board of Directors, may be taken without a meeting if all members of the Board of Directors or committee, as the case may be, consent thereto in writing, and the writing or writings are filed with the minutes of proceedings of the Board of Directors or committee. Such consent shall have the same force and effect as a unanimous vote at a meeting, and may be stated as such in any document or instrument filed with the Secretary of State of the state of incorporation of the Corporation. Unless otherwise restricted by the Certificate of Incorporation, subject to the requirement for notice of meetings, members of the Board of Directors, or members of any committee designated by the Board of Directors, may participate in a meeting of such Board of Directors or committee, as the case may be, by means of a conference telephone connection or similar communications equipment by means of which all persons participating in the meeting can hear each other, and participation in such a meeting shall constitute presence in person at such meeting, except where a person participates in the meeting for the express purpose of objecting to the transaction of any business on the ground that the meeting is not lawfully called or convened. SECTION 12. APPROVAL OR RATIFICATION OF ACTS OR CONTRACTS BY STOCKHOLDERS. The Board of Directors in its discretion may submit any act or contract for approval or ratification at any annual meeting of the stockholders, or at any special meeting of the stockholders called for the purpose of considering any such act or contract, and any act or contract that shall be approved or be ratified by the vote of the stockholders holding a majority of the issued and outstanding shares of stock of the Corporation entitled to vote and present in person or by proxy at such meeting (provided that a quorum is present) shall be as valid and as binding upon the Corporation and upon all the stockholders as if it has been approved or ratified by every stockholder of the Corporation. Article IV COMMITTEES SECTION 1. EXECUTIVE COMMITTEE. The Board of Directors may, by resolution passed by a majority of the whole Board of Directors, designate an Executive -10- Committee consisting of one or more of the directors of the Corporation, one of whom shall be designated chairman of the Executive Committee. During the intervals between the meetings of the Board of Directors, the Executive Committee shall possess and may exercise all the powers of the Board of Directors, including the power to authorize the seal of the Corporation to be affixed to all papers which may require it; provided, however, that the Executive Committee shall not have the power or authority of the Board of Directors in reference to amending the Certificate of Incorporation, adopting an agreement of merger or consolidation, recommending to the stockholders the sale, lease or exchange of all or substantially all of the Corporation's property and assets, recommending to the stockholders a dissolution of the Corporation or a revocation of a dissolution of the Corporation, amending, altering or repealing these Bylaws or adopting new bylaws for the Corporation or otherwise acting where action by the Board of Directors is specified by the Delaware General Corporation Law. The Executive Committee shall also have, and may exercise, all the powers of the Board of Directors, except as aforesaid, whenever a quorum of the Board of Directors shall fail to be present at any meeting of the Board. SECTION 2. AUDIT COMMITTEE. The Board of Directors may, by resolution passed by a majority of the whole Board of Directors, designate an Audit Committee consisting of one or more of the directors of the Corporation, one of whom shall be designated chairman of the Audit Committee. The Audit Committee shall have and may exercise such powers and authority as provided in the resolution creating it and as determined from time to time by the Board of Directors. SECTION 3. OTHER COMMITTEES. The Board of Directors may, by resolution passed from time to time by a majority of the whole Board of Directors, designate such other committees as it shall see fit consisting of one or more of the directors of the Corporation, one of whom shall be designated chairman of each such committee. Any such committee shall have and may exercise such powers and authority as provided in the resolution creating it and as determined from time to time by the Board of Directors. SECTION 4. PROCEDURE; MEETINGS; QUORUM. Any committee designated pursuant to this Article IV shall keep regular minutes of its actions and proceedings in a book provided for that purpose and report the same to the Board of Directors at its meeting next succeeding such action, shall fix its own rules or procedures, and shall meet at such times and at such place or places as may be provided by such rules, or by such committee or the Board of Directors. Should a committee fail to fix its own rules, the provisions of these Bylaws, pertaining to the calling of meetings and conduct of business by the Board of Directors, shall apply as nearly as may be. At every meeting of any such committee, the presence of a majority of all -11- the members thereof shall constitute a quorum, except as provided in Section 5 of this Article IV, and the affirmative vote of a majority of the members present shall be necessary for the adoption by it of any resolution. SECTION 5. SUBSTITUTION AND REMOVAL OF MEMBERS; VACANCIES. The Board of Directors may designate one or more directors as alternate members of any committee, who may replace any absent or disqualified member at any meeting of such committee. In the absence or disqualification of a member of a committee, the member or members present at any meeting and not disqualified from voting, whether or not constituting a quorum, may unanimously appoint another member of the Board of Directors to act at the meeting in the place of the absent or disqualified member. The Board of Directors shall have the power at any time to remove any member(s) of a committee and to appoint other directors in lieu of the person(s) so removed and shall also have the power to fill vacancies in a committee. Article V OFFICERS Section 1. NUMBER, TITLES AND TERM OF Office. The officers of the Corporation shall be a Chairman of the Board, a President, a President-North American Operations, a President-International Operations, one or more Vice Presidents (any one or more of whom may be designated Executive Vice President or Senior Vice President), a General Counsel, a Treasurer, a Secretary and such other officers as the Board of Directors may from time to time elect or appoint (including, but not limited to, a Vice Chairman of the Board, a Deputy Corporate Secretary, one or more Assistant Secretaries and one or more Assistant Treasurers). Each officer shall hold office until such officer's successor shall be duly elected and shall qualify or until such officer's death or until such officer shall resign or shall have been removed. Any number of offices may be held by the same person, unless the Certificate of Incorporation provides otherwise. Except for the Chairman of the Board and the Vice Chairman of the Board, no officer need be a director. SECTION 2. POWERS AND DUTIES OF THE CHAIRMAN OF THE BOARD. The Chairman of the Board shall be the chief executive officer of the Corporation. Subject to the control of the Board of Directors and the Executive Committee (if any), the Chairman of the Board shall have general executive charge, management and control of the properties, business and operations of the Corporation with all such powers as may be reasonably incident to such responsibilities; may agree upon and execute all leases, contracts, evidences of indebtedness and other obligations in the name of the Corporation and may sign all certificates for shares of capital stock of the Corporation; and shall have such other powers and duties as designated in -12- accordance with these Bylaws and as from time to time may be assigned to the Chairman of the Board by the Board of Directors. The Chairman of the Board shall preside at all meetings of the stockholders and of the Board of Directors. SECTION 3. POWERS AND DUTIES OF THE PRESIDENT, PRESIDENT-NORTH AMERICAN OPERATIONS, AND PRESIDENT-INTERNATIONAL OPERATIONS. (a) Unless the Board of Directors otherwise determines, the President shall have the authority to agree upon and execute all leases, contracts, evidences of indebtedness and other obligations in the name of the Corporation; and, unless the Board of Directors otherwise determines, the President shall, in the absence of the Chairman of the Board or if there be no Chairman of the Board, preside at all meetings of the stockholders and (should the President be a director) of the Board of Directors; and the President shall have such other powers and duties as designated in accordance with these Bylaws and as from time to time may be assigned to the President by the Board of Directors or the Chairman of the Board. (b) Unless the Board of Directors otherwise determines, the President-North American Operations shall have the authority to agree upon and execute all leases, contracts, evidences of indebtedness and other obligations in the name of the Corporation pertaining to the Corporation's North American operations; and the President-North American Operations shall have such other powers and duties as designated in accordance with these Bylaws and as from time to time may be assigned to the President-North American Operations by the Board of Directors or the Chairman of the Board. (c) Unless the Board of Directors otherwise determines, the President-International Operations shall have the authority to agree upon and execute all leases, contracts, evidences of indebtedness and other obligations in the name of the Corporation pertaining to the Corporation's international operations; and the President- International Operations shall have such other powers and duties as designated in accordance with these Bylaws and as from time to time may be assigned to the President-International Operations by the Board of Directors or the Chairman of the Board. SECTION 4. POWERS AND DUTIES OF THE VICE CHAIRMAN OF THE BOARD. The Board of Directors may assign areas of responsibility to the Vice Chairman of the Board, and, in such event, and subject to the overall direction of the Chairman of the Board and the Board of Directors, the Vice Chairman of the Board shall be responsible for supervising the management of the affairs of the Corporation and its subsidiaries within the area or areas assigned and shall monitor and review on behalf of the Board of Directors all functions within the corresponding area or areas of the -13- Corporation and each such subsidiary of the Corporation. In the absence of the President, or in the event of the President's inability or refusal to act, the Vice Chairman of the Board shall perform the duties of the President, and when so acting shall have all the powers of and be subject to all the restrictions upon the President. Further, the Vice Chairman of the Board shall have such other powers and duties as designated in accordance with these Bylaws and as from time to time may be assigned to the Vice Chairman of the Board by the Board of Directors or the Chairman of the Board. SECTION 5. VICE PRESIDENTS. Each Vice President shall at all times possess power to sign all certificates, contracts and other instruments of the Corporation, except as otherwise limited in writing by the Chairman of the Board, the President or the Vice Chairman of the Board or of the Corporation. Each Vice President shall have such other powers and duties as from time to time may be assigned to such Vice President by the Board of Directors, the Chairman of the Board, the President or the Vice Chairman of the Board. SECTION 6. GENERAL COUNSEL. The General Counsel shall act as chief legal advisor to the Corporation. The General Counsel may have one or more staff attorneys and assistants, and may retain other attorneys to conduct the legal affairs and litigation of the Corporation under the General Counsel's supervision. SECTION 7. SECRETARY. The Secretary shall keep the minutes of all meetings of the Board of Directors, committees of the Board of Directors and the stockholders, in books provided for that purpose; shall attend to the giving and serving of all notices; may in the name of the Corporation affix the seal of the Corporation to all contracts of the Corporation and attest the affixation of the seal of the Corporation thereto; may sign with the other appointed officers all certificates for shares of capital stock of the Corporation; shall have charge of the certificate books, transfer books and stock ledgers, and such other books and papers as the Board of Directors may direct, all of which shall at all reasonable times be open to inspection of any director upon application at the office of the Corporation during business hours; shall have such other powers and duties as designated in these Bylaws and as from time to time may be assigned to the Secretary by the Board of Directors, the Chairman of the Board, the President or the Vice Chairman of the Board; and shall in general perform all acts incident to the office of Secretary, subject to the control of the Board of Directors, the Chairman of the Board, the President or the Vice Chairman of the Board. SECTION 8. DEPUTY CORPORATE SECRETARY AND ASSISTANT SECRETARIES. The Deputy Corporate Secretary and each Assistant Secretary shall have the usual powers and duties pertaining to such offices, together with such other powers and duties as -14- designated in these Bylaws and as from time to time may be assigned to the Deputy Corporate Secretary or an Assistant Secretary by the Board of Directors, the Chairman of the Board, the President, the Vice Chairman of the Board, or the Secretary. The Deputy Corporate Secretary shall exercise the powers of the Secretary during that officer's absence or inability or refusal to act. SECTION 9. TREASURER. The Treasurer shall have responsibility for the custody and control of all the funds and securities of the Corporation, and shall have such other powers and duties as designated in these Bylaws and as from time to time may be assigned to the Treasurer by the Board of Directors, the Chairman of the Board, the President or the Vice Chairman of the Board. The Treasurer shall perform all acts incident to the position of Treasurer, subject to the control of the Board of Directors, the Chairman of the Board, the President and the Vice Chairman of the Board; and the Treasurer shall, if required by the Board of Directors, give such bond for the faithful discharge of the Treasurer's duties in such form as the Board of Directors may require. SECTION 10. ASSISTANT TREASURERS. Each Assistant Treasurer shall have the usual powers and duties pertaining to such office, together with such other powers and duties as designated in these Bylaws and as from time to time may be assigned to each Assistant Treasurer by the Board of Directors, the Chairman of the Board, the President, the Vice Chairman of the Board, or the Treasurer. The Assistant Treasurers shall exercise the powers of the Treasurer during that officer's absence or inability or refusal to act. SECTION 11. ACTION WITH RESPECT TO SECURITIES OF OTHER CORPORATIONS. Unless otherwise directed by the Board of Directors, the Chairman of the Board, the President or the Vice Chairman of the Board, together with the Secretary, the Deputy Corporate Secretary or any Assistant Secretary shall have power to vote and otherwise act on behalf of the Corporation, in person or by proxy, at any meeting of security holders of or with respect to any action of security holders of any other corporation in which this Corporation may hold securities and otherwise to exercise any and all rights and powers which this Corporation may possess by reason of its ownership of securities in such other corporation. SECTION 12. DELEGATION. FOR any reason that the Board of Directors may deem sufficient, the Board of Directors may, except where otherwise provided by statute, delegate the powers or duties of any officer to any other person, and may authorize any officer to delegate specified duties of such officer to any other person. Any such delegation or authorization by the Board shall be effected from time to time by resolution of the Board of Directors. -15- Article VI CAPITAL STOCK SECTION 1. CERTIFICATES OF STOCK. The certificates for shares of the capital stock of the Corporation shall be in such form, not inconsistent with that required by law and the Certificate of Incorporation, as shall be approved by the Board of Directors. Every holder of stock represented by certificates shall be entitled to have a certificate signed by or in the name of the Corporation by the Chairman of the Board, President, Vice Chairman of the Board or a Vice President and the Secretary, Deputy Corporate Secretary or an Assistant Secretary or the Treasurer or an Assistant Treasurer of the Corporation representing the number of shares (and, if the stock of the Corporation shall be divided into classes or series, certifying the class and series of such shares) owned by such stockholder which are registered in certified form; provided, however, that any of or all the signatures on the certificate may be facsimile. The stock record books and the blank stock certificate books shall be kept by the Secretary, or at the office of such transfer agent or transfer agents as the Board of Directors may from time to time determine. In case any officer, transfer agent or registrar who shall have signed or whose facsimile signature or signatures shall have been placed upon any such certificate or certificates shall have ceased to be such officer, transfer agent or registrar before such certificate is issued by the Corporation, such certificate may nevertheless be issued by the Corporation with the same effect as if such person were such officer, transfer agent or registrar at the date of issue. The stock certificates shall be consecutively numbered and shall be entered in the books of the Corporation as they are issued and shall exhibit the holder's name and number of shares. SECTION 2. TRANSFER OF SHARES. The shares of stock of the Corporation shall be transferable only on the books of the Corporation by the holders thereof in person or by their duly authorized attorneys or legal representatives upon surrender and cancellation of certificates for a like number of shares. Upon surrender to the Corporation or a transfer agent of the Corporation of a certificate for shares duly endorsed or accompanied by proper evidence of succession, assignment or authority to transfer, it shall be the duty of the Corporation to issue a new certificate to the person entitled thereto, cancel the old certificate and record the transaction upon its books. SECTION 3. OWNERSHIP OF SHARES. The Corporation shall be entitled to treat the holder of record of any share or shares of capital stock of the Corporation as the holder in fact thereof and, accordingly, shall not be bound to recognize any equitable or other claim to or interest in such share or shares on the part of any other person, -16- whether or not it shall have express or other notice thereof, except as otherwise provided by the laws of the state of incorporation of the Corporation. SECTION 4. REGULATIONS REGARDING CERTIFICATES. The Board of Directors shall have the power and authority to make all such rules and regulations as they may deem expedient concerning the issue, transfer and registration or the replacement of certificates for shares of capital stock of the Corporation. SECTION 5. LOST OR DESTROYED CERTIFICATES. The Board of Directors may determine the conditions upon which the Corporation may issue a new certificate of stock in place of a certificate theretofore issued by it which is alleged to have been lost, stolen or destroyed and may require the owner of such certificate or such owner's legal representative to give bond, with surety sufficient to indemnify the Corporation and each transfer agent and registrar against any and all losses or claims which may arise by reason of the alleged loss, theft or destruction of any such certificate or the issuance of such new certificate in the place of the one so lost, stolen or destroyed. Article VII MISCELLANEOUS PROVISIONS SECTION 1. FISCAL YEAR. The fiscal year of the Corporation shall begin on the first day of January of each year. SECTION 2. CORPORATE SEAL. The corporate seal shall be circular in form and shall have inscribed thereon the name of the Corporation and the state of its incorporation, which seal shall be in the charge of the Secretary and shall be affixed to certificates of stock, debentures, bonds, and other documents, in accordance with the direction of the Board of Directors or a committee thereof, and as may be required by law; however, the Secretary may, if the Secretary deems it expedient, have a facsimile of the corporate seal inscribed on any such certificates of stock, debentures, bonds, contracts or other documents. Duplicates of the seal may be kept for use by the Deputy Corporate Secretary or any Assistant Secretary. SECTION 3. NOTICE AND WAIVER OF NOTICE. Whenever any notice is required to be given by law, the Certificate of Incorporation or under the provisions of these Bylaws, said notice shall be deemed to be sufficient if given (i) by telegraphic, cable or wireless transmission (including by telecopy or facsimile transmission) or (ii) by deposit of the same in a post office box or by delivery to an overnight courier service company in a sealed prepaid wrapper addressed to the person entitled thereto at such person's post office address, as it appears on the records of the Corporation, and such notice shall be -17- deemed to have been given on the day of such transmission or mailing or delivery to courier, as the case may be. Whenever notice is required to be given by law, the Certificate of Incorporation or under any of the provisions of these Bylaws, a written waiver thereof, signed by the person entitled to notice, whether before or after the time stated therein, shall be deemed equivalent to notice. Attendance of a person, including without limitation a director, at a meeting shall constitute a waiver of notice of such meeting, except when the person attends a meeting for the express purpose of objecting, at the beginning of the meeting, to the transaction of any business because the meeting is not lawfully called or convened. Neither the business to be transacted at, nor the purpose of, any regular or special meeting of the stockholders, directors, or members of a committee of directors need be specified in any written waiver of notice unless so required by the Certificate of Incorporation or these Bylaws. SECTION 4. FACSIMILE SIGNATURES. In addition to the provisions for the use of facsimile signatures elsewhere specifically authorized in these Bylaws, facsimile signatures of any officer or officers of the Corporation may be used whenever and as authorized by the Board of Directors. SECTION 5. RELIANCE UPON BOOKS, REPORTS AND RECORDS. A member of the Board of Directors, or a member of any committee designated by the Board of Directors, shall, in the performance of such person's duties, be fully protected in relying in good faith upon the records of the Corporation and upon such information, opinion, reports or statements presented to the Corporation by any of the Corporation's officers or employees, or committees of the Board of Directors, or by any other person as to matters the member reasonably believes are within such other person's professional or expert competence and who has been selected with reasonable care by or on behalf of the Corporation. SECTION 6. APPLICATION OF BYLAWS. In the event that any provisions of these Bylaws is or may be in conflict with any law of the United States, of the state of incorporation of the Corporation or of any other governmental body or power having jurisdiction over this Corporation, or over the subject matter to which such provision of these Bylaws applies, or may apply, such provision of these Bylaws shall be inoperative to the extent only that the operation thereof unavoidably conflicts with such law, and shall in all other respects be in full force and effect. -18- Article VIII AMENDMENTS The Board of Directors shall have the power to adopt, amend and repeal from time to time Bylaws of the Corporation, subject to the right of the stockholders entitled to vote with respect thereto to amend or repeal such Bylaws as adopted or amended by the Board of Directors. -19- EX-10.1 3 SERVICES AGREEMENT EXHIBIT 10.1 SERVICES AGREEMENT This Agreement is made and entered into as of the 1st day of January, 1994, between Enron Corp, a Delaware corporation ("Enron"), and Enron Oil & Gas Company, a Delaware corporation ("EOG"). For and in consideration of the mutual promises and conditions contained herein, the parties hereto agree as follows: 1. In order to assist the continued and orderly conduct of certain corporate functions currently performed by Enron for the benefit of EOG, Enron agrees to provide and EOG agrees to purchase, subject to the terms and conditions set forth herein, certain corporate staff and support services (collectively, the "Services"). 2. This Agreement shall become effective and Enron shall make the Services available to EOG pursuant to the terms of this Agreement commencing on January 1, 1994, and shall continue thereafter for a period of 5 years (unless otherwise specified herein) and from year to year thereafter unless terminated upon written notice by either party 60 days prior to the anniversary date of this Agreement. 3. The parties understand and agree that the Services shall be substantially identical in nature and quality to the Services provided to EOG by Enron during the 12-month period prior to the effective date of this Agreement. In the event of a dispute over the nature and quality of the Services, or the calculation of Direct Charges, Operating Charges, Outsourced Charges or Allocated Charges (as defined in Paragraph 4.(i), 4.(ii), 4.(iii) and 4.(iv) hereof, respectively) relating to Services provided to EOG hereunder, the prior practice of Enron with respect to the Services previously provided to EOG or the calculation of Direct Charges, Operating Charges, Outsourced Charges and Allocated Charges relating to such Services, as determined from the books and records of Enron and EOG, shall be conclusive as to the nature and quality of the Services and the calculation of Direct Charges, Operating Charges, Outsourced Charges and Allocated Charges relating to such Services, as the case may be. 4. EOG, as compensation for the performance of the Services, agrees to reimburse Enron for: (i) all expenses actually incurred by Enron and readily identifiable to EOG relating to corporate staff and support services provided by Enron hereunder ("Direct Charges"), calculated in accordance with the prior practice of Enron with respect to the Services previously provided to EOG as indentified in EXHIBIT A attached hereto, which calculation shall be based on the cost of such Services to Enron (excepting the calculation of charges for "Rent and LHI" as indicated on Exhibit A for any square footage occupied during the term hereof), (ii) the actual cost of any goods or services purchased for EOG by Enron from third parties unaffiliated with Enron ("Operating Charges"), (iii) the actual cost or charge for outsourced services provided by any third party unaffiliated with Enron for EOG under an Enron or Enron affiliate agreement with such third party ("Outsourced Charges") 2 and (iv) an overhead allocation to EOG of administrative and general expenses of Enron corporate staff and support services, composed of those services as identified in Exhibit B attached hereto, and for which EOG does not receive Direct Charges ("Allocated Charges") allocated based upon the modified "Massachusetts" formula as applied to the interstate pipeline companies. Such Allocated Charges shall be payable in monthly installments; PROVIDED, however, that such Allocated Charges described in Paragraph 4.(iv) hereof during any year shall not exceed a maximum amount (the "Allocated Charge Ceiling" as such term is defined below) for such year. The Allocated Charge Ceiling for the year 1994 shall be $6,700,000. The Allocated Charge Ceiling for each year thereafter shall be adjusted annually, as hereinafter provided, for changes in the EOG components of the modified Massachusetts formula and for inflation; PROVIDED, however, that for the purpose of computing adjustments to the Allocated Charge Ceiling, the aggregate increase for any year shall not exceed 7.5% of the prior year's Allocated Charge Ceiling. The incremental amount of any increase in excess of 7.5% per year shall not be considered in computing adjustments to the Allocated Charge Ceiling for such period; PROVIDED FURTHER, however, that the parties hereto agree that the Allocated Charge Ceiling may be subject to good faith renegotiation in the event of an extraordinary change in the components thereof. 3 In the event of a change in the EOG components establishing EOG's percentage allocation of Allocated Charges pursuant to the modified Massachusetts formula, the Allocated Charge Ceiling shall be adjusted annually, to reflect such change, subject to the 7.5% limit on the aggregate increase set out above. Such annual adjustments shall be determined based upon data as of December 31 and are to be effected as soon as such information is available. In addition, but subject to the 7.5% limit on the aggregate increase set out above, the Allocated Charge Ceiling shall be changed based upon any change in the Consumer Price Index for all Urban Consumers as determined by the U.S. Department of Labor, Bureau of Labor Statistics (the "CPI-U"). For the purpose of computing such change, the parties hereto agree that the base period for the CPI-U is "1982/84 equals 100", and the CPI-U Index number for December 1993 is 146.30. CPI-U adjustments to the Allocated Charge Ceiling shall be made annually, based upon the CPI-U Index number for the month of December for the immediately preceeding year (such adjustments are to be effected upon publication of the CPI-U Index number for such month). Whenever a change occurs from the December 1993 Index number, the Allocated Charge Ceiling shall be adjusted as follows: the Allocated Charge Ceiling for the year 1994 shall be multiplied by a fraction, the numerator of which is the published CPI-U for the most recent month of December and the denominator of which is 146.30. In the event the Bureau of 4 Labor Statistics shifts the CPI-U referred to herein from the "1982/84 equals 100" base period to a different base period, EOG and Enron agree to use the rebasing factors published by the Bureau of Labor Statistics for converting the "1982/84 equals 100" base period to the new applicable base. In the event (i) with respect to the CPI-U, rebasing factors are not published or (ii) the CPI-U is discontinued, a proper index or classification with appropriate adjustment factors shall be substituted by written agreement between Enron and EOG. If the compensation for the Services does not include sales, use, excise, value added or similar taxes, and if any such taxes are imposed on the Services after the effective date of this Agreement, then such taxes shall be paid by EOG. Any change in the methodology to be used for determining any Direct Charges, Operating Charges, Outsourced Charges or Allocated Charges to EOG from that being used on the effective date of this Agreement shall be on a basis determined mutually agreeable to EOG and Enron prior to the implementation of such change. 5. Enron shall invoice EOG by the 15th working day of each month for all Direct Charges, Operating Charges, Outsourced Charges and Allocated Charges, all with respect to the preceding month. All invoices shall reflect in reasonable detail a description of the Services performed during the preceding month, and shall be due and payable on the last day of the month of the invoice. In the event of default in payment by EOG, and 5 if such payment is not made within thirty days after written notice is sent to EOG by certified mail to the address specified below, Enron may terminate this Agreement as to those Services which relate to the unpaid portion of the invoice by giving written notice of such election to EOG. In the event of a dispute as to the propriety of invoiced amounts, EOG shall pay all undisputed amounts on each invoice, but shall be entitled to withhold payment of any amount in dispute and shall promptly notify Enron of its dispute. Enron shall provide EOG with records relating to the disputed amount so as to enable the parties to resolve the dispute. So long as the parties are attempting in good faith to resolve the dispute, Enron shall not be entitled to terminate the Services related to and by reason of the disputed charge. 6. Any input necessary for Enron or any third party to perform any Services shall be submitted by EOG in a manner consistent with the practices utilized during the period prior to the effective date of this Agreement, which manner shall not be altered except by mutual written agreement of the parties. Should EOG's failure to supply such input render Enron's or any third party's performance of any Services unreasonably difficult, Enron or any third party, upon reasonable notice, may refuse to perform such Services until such input is supplied. 7. EOG acknowledges that the Services shall be provided only with respect to the business of EOG. EOG will not request performance of any Services for the benefit of any entity other 6 than EOG and its subsidiaries or affiliates. EOG represents and agrees that it will use the Services only in accordance with all applicable federal, state and local laws and regulations and communications and common carrier tariffs, and in accordance with the reasonable conditions, rules, regulations and specifications which may be set forth in any manuals, materials, documents or instructions in existence on the effective date of this Agreement and furnished by Enron to EOG. Enron or any third party reserves the right to take all actions, including termination of any particular Services, that Enron or any third party reasonably believes to be necessary to assure compliance with applicable laws, regulations and tariffs. 8. Enron will assign to EOG all user codes, passwords or numbers, or other control or identifying cards or numbers, necessary for Enron to perform the Services. EOG assumes full responsibility for selection and use of any such codes, passwords, cards or numbers that may be permitted or required in connection with the Services involved. 9. The Services will be of the same nature and quality as those provided to EOG during the 12-month period prior to the effective date of this Agreement. ALL PRODUCTS OBTAINED FOR EOG ARE AS IS, WHERE IS, WITH ALL FAULTS. NEITHER ENRON, ANY ENRON AFFILIATE NOR ANY THIRD PARTY PERFORMING ANY SERVICES HEREUNDER MAKE ANY WARRANTIES OR REPRESENTATIONS WHATSOEVER, EXPRESS OR IMPLIED, INCLUDING THE WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE 7 WITH RESPECT TO THE SERVICES RENDERED OR PRODUCTS OBTAINED FOR EOG. IN NO EVENT SHALL ENRON BE LIABLE TO EOG OR ANY OTHER PERSON FOR ANY INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES RESULTING FROM ANY ERROR IN THE PERFORMANCE OF SERVICES OR FROM THE BREACH OF THIS AGREEMENT, REGARDLESS OF ENRON OR ANY THIRD PARTY FAULT. TO THE EXTENT ANY THIRD PARTY HAS LIMITED ITS LIABILITY TO ENRON FOR SERVICES UNDER AN OUTSOURCING OR OTHER AGREEMENT, EOG AGREES TO BE BOUND BY SUCH LIMITATION OF LIABILITY FOR ANY PRODUCT OR SERVICE PROVIDED TO EOG BY SUCH THIRD PARTY UNDER ENRON'S AGREEMENT. Enron shall have no obligation to perform the Services if its failure to do so is caused by or results from any act of God, governmental action, natural disaster, strike, failure of essential equipment or any other cause or circumstance beyond the control of Enron. Enron agrees that upon restoring service following any failure of any equipment necessary for Enron to provide any Services, Enron will allow EOG to have equal priority, in accordance with prior practice, with respect to access to the restored service. At its election, Enron may cause one or more of its subsidiaries (other than EOG), affiliates or third party contractors to provide the services called for by this Agreement; however, such action shall not release Enron from its obligations under this Agreement. 10. In the event any portion of this Agreement shall be found by a court of competent jurisdiction to be unenforceable, 8 that portion of the Agreement will be null and void and the remainder of the Agreement will be binding on the parties as if the unenforceable provisions had never been contained herein. 11. This Agreement shall not be assignable by either of the parties hereto except by operation of law. 12. This Agreement constitutes the entire agreement of the parties relating to the performance of the Services and all prior or contemporaneous written or oral agreements are merged herein. This Agreement may not be changed except by a writing signed by both parties. This Agreement shall be governed by the laws of the State of Texas. 13. Any notice, request, instruction, correspondence or other document to be given hereunder by either party to the other (herein collectively called "Notice") shall be in writing and delivered personally or mailed, postage prepaid, or by facsimile or telegram, as follows: If to Enron: Enron Corp. 1400 Smith Street P. O. Box 1188 Houston, Texas 77251-1188 Attention: Senior Vice President, Chief Information, Accounting and Administrative Officer Facsimile No.: 713-853-3920 9 If to EOG: Enron Oil & Gas Company 1400 Smith Street P. O. Box 1188 Houston, Texas 77251-1188 Attention: Senior Vice President and Chief Financial Officer Facsimile No.: 713-646-2548 Notice given by personal delivery or mail shall be effective upon actual receipt by the party to whom addressed. Notice given by facsimile or telegram shall be effective upon actual receipt if received during the recipient's normal business hours, or at the beginning of the recipient's next business day after receipt if not received during the recipient's normal business hours. Any party may change any address to which Notice is to be given to it by giving Notice as provided above of such change of address. IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be signed on their behalf by their duly authorized officers. ENRON CORP. By: Jack I. Tompkins Title: Senior Vice President, Chief Information, Accounting and Administrative Officer ENRON OIL & GAS COMPANY By: Walter C. Wilson Title: Senior Vice President and Chief Financial Officer 10 EXHIBIT A DIRECT CHARGE SERVICES TO EOG 1994 PLAN ENE CHARGE EXAMPLE RC# DESCRIPTION BASIS CHARGES CHARGED TO EOG FOR DIRECT INCURRED COSTS PENSION, THRIFT & MEDICAL 0030 Retiree Medical Head Count 343,188 0403 Retiree Medical (FAS 106) Head Count 612,844 0706 Retiree Prescription Head Count 313,772 2320 Savings Plan Head Count 0 2321 Retirement Plan Head Count 500,376 2322 ESOP Head Count 0 2323 EE Life, AD&D Dep Head Count 186,304 2324 Long Term Disability Head Count 156,888 2325 Supp. Exec. Retirement Plan Head Count 372,548 2326 ESOP Admin. Fees Head Count 20,592 2332 Flex Comp.-Admin. Chgs. Head Count 44,124 2333 Business Travel Insurance Head Count 2,162 2356 Adm. fees for Met Life Head Count 245,140 2329 Medical Plan Head Count 2,043,969 2330 HMO Premiums Head Count 2,940 2331 Drug Plan-Admin. Chrgs. Head Count 264,744 2336 Dental Plan Head Count 78,440 TOTAL PENSION, THRIFT & MEDICAL 5,188,031 COMPENSATION PLANS 2314 Restricted Stock Transactions 96,990 AVIATION 0781 Aviation Reservation Fee Usage 828,850 0782 Aviation Usage Usage 318,450 TOTAL AVIATION 1,147,300 DIRECT CHARGE SERVICES TO EOG 1994 PLAN ENE CHARGE EXAMPLE RC# DESCRIPTION BASIS CHARGES CHARGED TO EOG FOR DIRECT INCURRED COSTS BUILDING FACILITIES & SERVICES Building Rent & Related Costs 0566 Construction Services Usage 120,000 0580 Facility Planning Usage 30,000 0581 Facility Maintenance EB Space 57,200 0629 Corporate Security EB Space 74,500 0666 Recycling Head Count 2,600 0692 EPCO-Churn Relocation Usage 2,000 0898 Office Relocation/Furniture EB Space 38,300 2234 Facilities Operations EB Space 58,900 2441 Building Utilities EB Space 42,000 2455 Building Rent and LHI (@ $13.50 per square foot) EB Space 1,755,400 Total Bldg. Rent & Related Costs 2,180,900 Parking Garage Svcs. & Transp. Subs. 0060 Service Garage Usage 1,020 2478 Parking Usage 43,000 2479 Pool Cars Usage 0 2334 Transportation Subsidy Head Count 39,220 Total Parking Garage Svs. & Transp. Subs. 83,240 Copy, Graphics & Audio Visual Svcs. 0217 Micrographics Services Usage 16,635 0224 Forms Management Usage 45,000 0226 Photographic Services Usage 0 0228 Copier Center Usage 80,000 0339 Artistic Services Usage 60,000 0703 Audio Visual Services Usage 4,900 2255 Convenience Copiers Usage 100,100 Total Copy, Graphics & Audio Visual Svcs. 306,635 Mail, Shipping & Receiving 0103 Shipping & Receiving Usage 65,000 0492 Mail Center Usage 213,000 Total Mail, Shipping & Receiving 278,000 DIRECT CHARGE SERVICES TO EOG 1994 PLAN ENE CHARGE EXAMPLE RC# DESCRIPTION BASIS CHARGES CHARGED TO EOG FOR DIRECT INCURRED COSTS Records Related Costs 0215 Record Center Houston Usage 57,000 0489 Records & Info Management Usage 17,500 Total Records Related Costs 74,500 Office Supplies 0493 Office Supplies Usage 0 Real Estate Management 0075 EPCO Administration Usage 0 0508 Real Estate Management Usage 0 0752 EPCO Legal Services Usage 8,805 2434 Title Survey Usage 0 Total Real Estate Management 8,805 Health & Employee Services 0077 Travel Department Usage 0 0647 Health & Employee Svc. Head Count 51,204 2453 Cafeteria Head Count 72,867 2454 Body Shop Head Count 68,950 2460 Employee Recreation Head Count 8,109 2473 Special Functions Head Count 0 2474 Vending Head Count 0 2475 Coffee Head Count 10,174 2477 Corporate Special Events Head Count 8,100 Total Health & Employee Services 219,404 Telecommunications 2357 Telecomm. Houston Operations Usage 540,491 TOTAL BUILDING FACILITIES & SERVICES 3,691,975 OUTSIDE PROFESSIONAL SERVICES 2349 Outside Auditing Fees Per AA&Co. 217,000 0408 Contract Audit Services Per AA&Co. 650,000 TOTAL OUTSIDE PROFESSIONAL SERVICES 867,000 INSURANCE 2411 Insurance Premiums/Cost Liab.-Hd. Cnt. 2,697,648 Prop.-Prop. Value DIRECT CHARGE SERVICES TO EOG 1994 PLAN ENE CHARGE EXAMPLE RC# DESCRIPTION BASIS CHARGES CHARGED TO EOG FOR DIRECT INCURRED COSTS DATA PROCESSING COSTS EIS Charges Usage 327,925 EDS Charges Usage 2,086,970 TOTAL DATA PROCESSING COSTS 2,414,895 TOTAL DIRECT INCURRED COSTS 16,103,839 DIRECT CHARGE SERVICES TO EOG 1994 PLAN ENE CHARGE EXAMPLE RC# DESCRIPTION BASIS CHARGES CHARGED TO EOG FOR ABOVE DIRECT INCURRED COSTS H.R. & BENEFITS RELATED 0208 Compensation & Benefits Head Count 74,308 0213 H.R. Svcs.-Safety Head Count 8,000 0319 Corporate Human Resources Head Count 63,994 0246 Payroll Head Count 164,837 0386 H.R. Svcs.-Severance Head Count 2,200 0632 Special Projects Information Head Count 258,271 0649 Benefits Accounting Head Count 225,776 0658 Corp. Org. Development & Training Head Count 51,982 2242 Fair Employment Head Count 48,684 TOTAL H.R. & BENEFITS RELATED 898,052 TREASURY, FINANCE & RISK MANAGEMENT 0410 Risk Management Premiums 120,200 0451 Treasury Usage 198,872 0453 Corporate Finance Usage 151,136 TOTAL TREASURY, FINANCE & RISK MANAGEMENT 470,208 TAX 0441 State Tax Group Usage 30,000 0564 Ad Valorem Tax Dept. Prop Basis 138,600 TOTAL TAX 168,600 LEGAL 0860 Corporate Legal Usage 53,717 0861 Environmental Legal Usage 40,100 2416 Legal Library Attny. Hd. Cnt. 24,497 TOTAL LEGAL 118,314 INVESTOR RELATIONS 0405 Investor Relations Usage 88,750 MISCELLANEOUS 2381 Corp. Contributions-Houston Actual 69,600 TOTAL FOR CHARGES ABOVE INCURRED COSTS 1,714,476 TOTAL DIRECT CHARGES 17,917,363 EXHIBIT B ALLOCATED CHARGE SERVICES TO EOG 1994 PLAN TOTAL EOG ENRON EXAMPLE ENE CORP. CHARGES RC# DESCRIPTION INDIRECT AT 19.38% (1) 0138 Corporate Financial Accounting 1,745,500 338,278 1400 Enron Corp. Billing 13,223,657 2,562,745 0137 Corporate Financial Planning 670,500 129,943 0303 Sr. VP CIAAO 589,800 114,303 0304 President and COO 1,109,600 215,040 0305 Chief of Staff 701,700 135,989 0308 Executive Reception 267,900 51,919 0445 Vice President - Tax 1,746,800 338,530 0460 Corporate Development 734,800 142,404 0588 Sr. VP and Treasurer 591,717 114,675 0610 Corporate Secretary 1,490,800 288,917 0808 Govt. Affairs Public & Policy 613,960 118,985 0866 Federal Government Affairs 1,043,200 202,172 0870 State Governmental Affairs 684,600 132,675 0890 Chairman and CEO 1,740,600 337,328 2001 Corporate Aircraft Usage 3,087,280 598,315 2315 NQ Stock Plan 420,000 81,396 2317 Exec Perqs 54,100 10,485 2318 Employee Performance Awards 147,000 28,489 2394 European Investor Relations 95,000 18,411 2396 Corporate Memberships 425,000 82,365 2397 Employee Communications 933,600 180,932 2398 Corp. Communications 510,100 98,857 2399 Media Relations 910,900 176,532 2418 Executive Board Meeting Expenses 725,000 140,505 TOTAL 34,263,114 6,640,190 (1) Percentage calculated including all operating units and EOTT Energy Services EX-10.15 4 REVOLVING CREDIT AGREEMENT EXHIBIT 10.15 U.S. $100,000,000 REVOLVING CREDIT AGREEMENT Dated as of March 11, 1994 Among ENRON OIL & GAS COMPANY as Borrower and THE BANKS NAMED HEREIN as Banks and TEXAS COMMERCE BANK NATIONAL ASSOCIATION as Administrative Agent TABLE OF CONTENTS Section Page ARTICLE I DEFINITIONS AND ACCOUNTING TERMS 1.1. Certain Defined Terms . . . . . . . . . . . . . . . . . 1 1.2. Computation of Time Periods . . . . . . . . . . . . . . 10 1.3. Accounting Terms . . . . . . . . . . . . . . . . . . . 10 1.4. Miscellaneous . . . . . . . . . . . . . . . . . . . . . 10 1.5. Ratings . . . . . . . . . . . . . . . . . . . . . . . . 10 ARTICLE II AMOUNT AND TERMS OF THE ADVANCES 2.1. The Advances . . . . . . . . . . . . . . . . . . . . . 11 2.2. Making the Advances . . . . . . . . . . . . . . . . . . 11 2.3. Fees . . . . . . . . . . . . . . . . . . . . . . . . . 12 2.4. Repayment . . . . . . . . . . . . . . . . . . . . . . . 13 2.5. Interest . . . . . . . . . . . . . . . . . . . . . . . 13 2.6. Additional Interest on Eurodollar Advances . . . . . . 14 2.7. Interest Rate Determination and Protection . . . . . . 14 2.8. Voluntary Conversion of Advances . . . . . . . . . . . 16 2.9. Prepayments . . . . . . . . . . . . . . . . . . . . . . 16 2.10.Increased Costs; Capital Adequacy, Etc. . . . . . . . . 17 2.11.Illegality . . . . . . . . . . . . . . . . . . . . . . 19 2.12.Payments and Computations . . . . . . . . . . . . . . . 19 2.13.Taxes . . . . . . . . . . . . . . . . . . . . . . . . . 20 2.14.Sharing of Payments, Etc. . . . . . . . . . . . . . . . 22 2.15.Increase of Commitment . . . . . . . . . . . . . . . . 23 2.16.Ratable Reduction or Termination of the Commitments . . 23 2.17.Non-Ratable Reduction or Termination of Commitment . . 23 2.18.Replacement of Bank . . . . . . . . . . . . . . . . . . 24 ARTICLE III CONDITIONS TO ADVANCES 3.1. Initial Conditions Precedent . . . . . . . . . . . . . 25 3.2. Additional Conditions Precedent to Each Advance . . . . 25 ARTICLE IV REPRESENTATIONS AND WARRANTIES 4.1. Representations and Warranties of the Borrower . . . . 25 ARTICLE V COVENANTS OF THE BORROWER 5.1. Affirmative Covenants . . . . . . . . . . . . . . . . . 28 5.2. Negative Covenants . . . . . . . . . . . . . . . . . . 31 ARTICLE VI EVENTS OF DEFAULT 6.1. Events of Default . . . . . . . . . . . . . . . . . . . 32 ARTICLE VII THE ADMINISTRATIVE AGENT 7.1. Authorization and Action . . . . . . . . . . . . . . . 35 7.2. Administrative Agent's Reliance, Etc. . . . . . . . . . 35 7.3. Administrative Agent and Its Affiliates . . . . . . . . 36 7.4. Bank Credit Decision . . . . . . . . . . . . . . . . . 36 7.5. Certain Rights of the Administrative Agent . . . . . . 36 7.6. Holders . . . . . . . . . . . . . . . . . . . . . . . . 37 7.7. Indemnification . . . . . . . . . . . . . . . . . . . . 37 7.8. Resignation by the Administrative Agent . . . . . . . . 38 ARTICLE VIII MISCELLANEOUS 8.1. Amendments, Etc. . . . . . . . . . . . . . . . . . . . 38 8.2. Notices, Etc. . . . . . . . . . . . . . . . . . . . . . 39 8.3. No Waiver; Remedies . . . . . . . . . . . . . . . . . . 40 8.4. Costs, Expenses and Taxes . . . . . . . . . . . . . . . 40 8.5. Right of Set-Off . . . . . . . . . . . . . . . . . . . 41 8.6. Binding Effect; Assignments; Participations . . . . . . 41 8.7. Governing Law; Entire Agreement . . . . . . . . . . . . 43 8.8. Interest . . . . . . . . . . . . . . . . . . . . . . . 43 8.9. Captions . . . . . . . . . . . . . . . . . . . . . . . 44 8.10.Confidentiality . . . . . . . . . . . . . . . . . . . . 44 8.11.Survival; Term; Reinstatement . . . . . . . . . . . . . 44 8.12.Severability . . . . . . . . . . . . . . . . . . . . . 45 8.13.Chapter 15 Not Applicable . . . . . . . . . . . . . . . 45 8.14.Execution in Counterparts . . . . . . . . . . . . . . . 45 8.15.Waiver of Notice . . . . . . . . . . . . . . . . . . . 45 Schedule I - Facility Fees and Applicable Margin Schedule II - Applicable Lending Offices Exhibit A - Form of Note Exhibit B - Notice of Borrowing Exhibit C - Opinion of Vinson & Elkins L.L.P., Counsel to Borrower Exhibit D - Opinion of Vice President and General Counsel of Borrower Exhibit E - Notice of Conversion Exhibit F - Terms of Negative Pledge REVOLVING CREDIT AGREEMENT Dated as of March 11, 1994 ENRON OIL & GAS COMPANY, a Delaware corporation (the "BORROWER"), the lenders party hereto (the "BANKS") and TEXAS COMMERCE BANK NATIONAL ASSOCIATION, as administrative agent (in such capacity, the "ADMINISTRATIVE AGENT") for the Banks hereunder, agree as follows: ARTICLE I DEFINITIONS AND ACCOUNTING TERMS 1.1. CERTAIN DEFINED TERMS. As used in this Agreement, the following terms shall have the following meanings (such meanings to be equally applicable to both the singular and the plural forms of the terms defined): "ADJUSTED CD RATE" means, for any Interest Period for each Adjusted CD Rate Advance comprising part of the same Borrowing, an interest rate per annum equal to the sum of: (a) the rate per annum obtained by dividing (1) the rate of interest determined by the Administrative Agent to be the average (rounded upward to the nearest whole multiple of 1/100 of 1% per annum, if such average is not such a multiple) of the consensus bid rate determined by each of the Reference Banks for the bid rates per annum, at 9:00 A.M. (or as soon thereafter as practicable) one Business Day before the first day of such Interest Period, of New York certificate of deposit dealers of recognized standing selected by such Reference Bank for the purchase at face value of certificates of deposit of such Reference Bank in an amount substantially equal to such Reference Bank's Adjusted CD Rate Advance comprising part of such Borrowing and with a maturity equal to such Interest Period (provided that, if bid rate quotes from such dealers are not available to any Reference Bank, such Reference Bank shall notify the Administrative Agent of a reasonably equivalent rate determined by it on the basis of another source or sources selected by it), by (2) a percentage equal to 100% minus the Adjusted CD Rate Reserve Percentage for such Interest Period, plus (b) the Assessment Rate for such Interest Period. The Adjusted CD Rate for the Interest Period for each Adjusted CD Rate Advance comprising part of the same Borrowing shall be determined by the Administrative Agent on the basis of applicable rates furnished to and received by the Administrative Agent from the Reference Banks one Business Day before the first day of such Interest Period, SUBJECT HOWEVER, to the provisions of SECTION 2.7. -1- "ADJUSTED CD RATE ADVANCE" means an Advance which bears interest as provided in SECTION 2.5(b). "ADJUSTED CD RATE RESERVE PERCENTAGE" for any Interest Period for each Adjusted CD Rate Advance comprising part of the same Borrowing means the reserve percentage applicable one Business Day before the first day of such Interest Period under regulations issued from time to time by the Federal Reserve Board for determining the maximum reserve requirement (including, but not limited to, any emergency, supplemental or other marginal reserve requirement) for a member bank of the Federal Reserve System in New York City with deposits exceeding one billion dollars with respect to liabilities consisting of or including (among other liabilities) U.S. dollar nonpersonal time deposits in the United States with a maturity equal to such Interest Period. "ADVANCE" means an advance by a Bank to the Borrower pursuant to ARTICLE II, and refers to an Adjusted CD Rate Advance, a Base Rate Advance or a Eurodollar Advance (each of which shall be a "TYPE" of Advance). "ADMINISTRATIVE AGENT" shall have the meaning specified in the first paragraph of this Agreement, together with any successor thereto pursuant to SECTION 7.8. "AGREEMENT" means this Revolving Credit Agreement, as amended, supplemented or modified from time to time in the future. "APPLICABLE LENDING OFFICE" means, with respect to each Bank, such Bank's Domestic Lending Office in the case of a Base Rate Advance, such Bank's CD Lending Office in the case of an Adjusted CD Rate Advance and such Bank's Eurodollar Lending Office in the case of a Eurodollar Advance. "APPLICABLE MARGIN" means, for any Interest Period for each Adjusted CD Rate Advance comprising part of the same Borrowing and for any Interest Period for each Eurodollar Advance comprising part of the same Borrowing, the percentage per annum applicable to such Interest Period for such Advance as shown in SCHEDULE I and being based on (a) the Type of Advance to which such Interest Period relates (I.E., Adjusted CD Rate Advance or Eurodollar Advance), (b) the Rating Level, which for the purposes of determining the Applicable Margin shall be the Rating Level in effect on the first day of such Interest Period, and (c) the Percentage of Facility Usage, which for the purpose of determining the Applicable Margin shall be the Percentage of Facility Usage in effect on the first day of such Interest Period (after giving effect to the Advances for which the Applicable Margin is being determined). "ASSESSMENT RATE" for any Interest Period for each Adjusted CD Rate Advance comprising part of the same Borrowing means the annual assessment rate estimated by the Bank which is the Administrative Agent one Business Day before the first day of such Interest Period for determining the then current annual assessment payable by such Bank to the FDIC for insuring dollar deposits of such Bank at its principal office in the United States. -2- "BANKRUPTCY CODE" means Title 11 of the United States Code, as now or hereafter in effect, or any successor thereto. "BANKS" has the meaning specified in the first paragraph of this Agreement, and shall include any financial institution which becomes a Bank pursuant to SECTION 2.15, SECTION 2.18 or SECTION 8.6. "BASE RATE" at any time shall mean the higher of (a) the Prime Commercial Lending Rate as in effect from time to time and (b) the Federal Funds Rate plus 1/2 of 1%. If for any reason the Administrative Agent shall have determined (which determination shall be conclusive absent manifest error) that it is unable to ascertain the Federal Funds Rate for any reason, including the inability or failure of the Administrative Agent to obtain sufficient bids or publications in accordance with the terms hereof, the Base Rate shall be the Prime Commercial Lending Rate until the circumstances giving rise to such inability no longer exist. "BASE RATE ADVANCE" means an Advance which bears interest as provided in SECTION 2.5(a). "BORROWER" means Enron Oil & Gas Company, a Delaware corporation, and any successor thereto pursuant to SECTION 5.2(d). "BORROWING" means a borrowing hereunder consisting of Advances of the same Type made on the same day by the Banks. "BUSINESS DAY" means (a) any day of the year except Saturday, Sunday and any day on which banks are required or authorized to close in Houston, Texas or New York, New York, and (b) if the applicable Business Day relates to any Eurodollar Advances, any day which is a "Business Day" described in CLAUSE (a) and which is also a day for trading by and between banks in the applicable interbank Eurodollar market. "CD LENDING OFFICE" means, with respect to any Bank, the office of such Bank specified as its "CD Lending Office" opposite its name on SCHEDULE II hereto or in the document pursuant to which it became a party hereto as contemplated by SECTION 2.15, 2.18 or 8.6(b) (or, if no such office is specified, its Domestic Lending Office) or such other office of such Bank as such Bank may from time to time specify to the Borrower and the Administrative Agent. "CHAPTER ONE" shall mean Chapter One of the Texas Credit Code, as in effect on the date the document using such term was executed. "CODE" means the Internal Revenue Code of 1986, as amended from time to time, or any successor Federal tax code, and any reference to any statutory provision of the Code shall be deemed to be a reference to any successor provision or provisions. "COMMITMENT" has the meaning specified in SECTION 2.1. -3- "CONSOLIDATED" refers to the consolidation of the accounts of the Borrower and its Subsidiaries in accordance with GAAP. "CONSOLIDATED NET WORTH" means at any date the Consolidated shareholders' equity of the Borrower and its Consolidated Subsidiaries. "CONVERT", "CONVERSION" and "CONVERTED" each refers to a conversion of Advances of one Type into Advances of another Type pursuant to SECTION 2.7, SECTION 2.8 or SECTION 2.10(b). "DEBT" of any Person means, at any date, without duplication, (a) obligations for the repayment of money borrowed which (1) are evidenced by bonds, notes, debentures, loan agreements, credit agreements or similar instruments or agreements and (2) are or should be shown on a balance sheet as debt in accordance with GAAP, (b) obligations as lessee under leases which, in accordance with GAAP, are capital leases, and (c) guaranties of payment or collection of any obligations described in CLAUSES (a) and (b) of other Persons, PROVIDED, that CLAUSES (a) and (b) include, in the case of obligations of the Borrower or any Subsidiary, only such obligations as are or should be shown as debt or capital lease liabilities on a Consolidated balance sheet in accordance with GAAP; PROVIDED, FURTHER, that none of the following shall constitute Debt: (A) transfers of accounts receivable pursuant to a receivables purchase facility considered as a sale under GAAP (and indemnification, recourse or repurchase obligations thereunder as are reasonable given market standards for transactions of similar type), (B) the liability of any Person as a general partner of a partnership for Debt of such partnership, if the partnership is not a Subsidiary of such Person, and (C) obligations (other than borrowings, capital leases or financial guaranties by the Borrower or any Subsidiary) related to the sale, purchase or delivery of hydrocarbons in respect of volumetric production payments conveyed in transfers constituting sales of real property interests for which proceeds are accounted for as deferred revenues under GAAP. "DOMESTIC LENDING OFFICE" means, with respect to any Bank, the office of such Bank specified as its "Domestic Lending Office" opposite its name on SCHEDULE II or in the document pursuant to which it became a party hereto as contemplated by SECTION 2.15, 2.18 or 8.6(b) or such other office of such Bank as such Bank may from time to time specify to the Borrower and the Administrative Agent. "ERISA" means the Employee Retirement Income Security Act of 1974, as amended from time to time, and any successor statute of similar import, together with the regulations thereunder, as in effect from time to time. "ERISA AFFILIATE" means any trade or business (whether or not incorporated) which is a member of a group of which the Borrower is a member and which is under common control within the meaning of the regulations under Section 414 of the Code. -4- "EUROCURRENCY LIABILITIES" has the meaning assigned to that term in Regulation D of the Federal Reserve Board, as in effect from time to time. "EURODOLLAR ADVANCE" means an Advance which bears interest as provided in SECTION 2.5(c). "EURODOLLAR LENDING OFFICE" means, with respect to any Bank, the office of such Bank specified as its "Eurodollar Lending Office" opposite its name on SCHEDULE II or in the document pursuant to which it became a party hereto as contemplated by SECTION 2.15, 2.18 or 8.6(b) (or, if no such office is specified, its Domestic Lending Office) or such other office of such Bank as such Bank may from time to time specify to the Borrower and the Administrative Agent. "EURODOLLAR RATE" means, for any Interest Period for each Eurodollar Advance comprising part of the same Borrowing, the lesser of (a) an interest rate per annum equal to the average (rounded upward to the nearest whole multiple of 1/16 of 1% per annum, if such average is not such a multiple) of the rate per annum at which dollar deposits in immediately available funds for delivery on the first day of such Interest Period are offered by each of the Reference Banks to leading banks in the interbank Eurodollar market selected by the Administrative Agent at approximately 11:00 A.M. (local time in the relevant Eurodollar market) two Business Days before the first day of such Interest Period in an amount substantially equal to the amount of the Eurodollar Advance of such Reference Bank comprising part of such Borrowing to be outstanding during such Interest Period and for a period equal to such Interest Period and (b) the Highest Lawful Rate. The Eurodollar Rate for each Interest Period for each Eurodollar Advance comprising part of the same Borrowing shall be determined by the Administrative Agent on the basis of applicable rates furnished to and received by the Administrative Agent from the Reference Banks two Business Days before the first day of such Interest Period, SUBJECT, HOWEVER, to the provisions of SECTION 2.7. "EVENTS OF DEFAULT" has the meaning specified in SECTION 6.1. "FDIC" means the Federal Deposit Insurance Corporation, or any federal agency or authority of the United States from time to time succeeding to its function. "FEDERAL FUNDS RATE" means, for any period, a fluctuating interest rate per annum equal for each day during such period to the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System arranged by Federal funds brokers, as published for such day (or, if such day is not a Business Day, for the next preceding Business Day) by the Federal Reserve Bank of New York, or, if such rate is not so published for any day which is a Business Day, the average of the quotations for such day on such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by it. -5- "FEDERAL RESERVE BOARD" means the Board of Governors of the Federal Reserve System, or any federal agency or authority of the United States from time to time succeeding to its function. "GAAP" means generally accepted accounting principles consistent with those applied in the preparation of the audited consolidated financial statements referred to in SECTION 4.1(d). "HIGHEST LAWFUL RATE" shall mean, on any day, the maximum nonusurious rate of interest permitted for that day by whichever of applicable federal or Texas law permits the higher interest rate, stated as a rate per annum. On each day, if any, that Chapter One establishes the Highest Lawful Rate, the Highest Lawful Rate shall be the "indicated rate ceiling" (as defined in Chapter One) for that day. "INDENTURE" means that certain Indenture dated as of September 1, 1991 between the Borrower and Texas Commerce Bank National Association, as Trustee, without giving effect to any amendment, modification or discharge thereof. "INSUFFICIENCY" means, with respect to any Plan, the amount, if any, by which the present value of the accrued benefits under such Plan exceeds the fair market value of the assets of such Plan allocable to such benefits. "INTEREST PERIOD" means, with respect to each Adjusted CD Rate Advance or Eurodollar Advance, in each case comprising part of the same Borrowing, the period commencing on the date of such Advance or the date of the Conversion of any Advance into such an Advance and ending on the last day of the period selected by the Borrower pursuant to the provisions below and, thereafter, each subsequent period commencing on the last day of the immediately preceding Interest Period and ending on the last day of the period selected by the Borrower pursuant to the provisions below except that any Interest Period for Eurodollar Advances which commences on any day for which there is no numerically corresponding day in the appropriate subsequent calendar month shall end on the last Business Day of the appropriate subsequent calendar month. The duration of each such Interest Period shall be (a) in the case of an Adjusted CD Rate Advance, 30, 60, 90 or 180 days and (b) in the case of a Eurodollar Advance, one, two, three or six months, in each case as the Borrower may, upon notice received by the Administrative Agent not later than 11:00 A.M. on the third Business Day (first Business Day in the case of an Adjusted CD Rate Advance) prior to the first day of such Interest Period, select; PROVIDED, HOWEVER, that: (1) Interest Periods commencing on the same date for Advances comprising part of the same Borrowing shall be of the same duration; (2) whenever the last day of any Interest Period would otherwise occur on a day other than a Business Day, the last day of such Interest Period shall be extended to occur on the next succeeding Business Day, PROVIDED, in the case of any Interest Period -6- for a Eurodollar Advance, that if such extension would cause the last day of such Interest Period to occur in the next following calendar month, the last day of such Interest Period shall occur on the next preceding Business Day; and (3) no Interest Period may end after the Termination Date. "LOAN DOCUMENT" means this Agreement, each Note, each Notice of Borrowing and each other document or instrument executed and delivered in connection with this Agreement. "MAJORITY BANKS" means at any time Banks holding at least 66 2/3% of the then aggregate unpaid principal amount of the Notes held by Banks, or, if no such principal amount is then outstanding, Banks having at least 66 2/3% of the Commitments. "MOODY'S" means Moody's Investors Service, Inc. "MULTIEMPLOYER PLAN" means a "multiemployer plan" as defined in Section 4001(a)(3) of ERISA to which the Borrower or any ERISA Affiliate is making or accruing an obligation to make contributions, or has within any of the preceding five plan years made or accrued an obligation to make contributions. "MULTIPLE EMPLOYER PLAN" means an employee benefit plan, other than a Multiemployer Plan, subject to Title IV of ERISA to which the Borrower or any ERISA Affiliate, and more than one employer other than the Borrower or an ERISA Affiliate, is making or accruing an obligation to make contributions or, in the event that any such plan has been terminated, to which the Borrower or any ERISA Affiliate made or accrued an obligation to make contributions during any of the five plan years preceding the date of termination of such plan. "NOTE" means a promissory note of the Borrower payable to the order of any Bank, in substantially the form of EXHIBIT A, evidencing the aggregate indebtedness of the Borrower to such Bank resulting from the Advances owed to such Bank. "NOTICE OF BORROWING" has the meaning specified in SECTION 2.2. "OTHER TAXES" has the meaning specified in SECTION 2.13(c). "PAYMENT OFFICE" means the office of the Administrative Agent located at 712 Main Street, Houston, Texas or such other office as the Administrative Agent may designate by written notice to the other parties hereto. "PBGC" means the Pension Benefit Guaranty Corporation, or any federal agency or authority of the United States from time to time succeeding to its function. -7- "PERCENTAGE OF FACILITY USAGE" means, as of any date of determination, the quotient (expressed as a percentage) obtained by dividing the aggregate unpaid principal amount of the Notes at the close of business on such date by the aggregate Commitments at the close of business on such date. "PERSON" means an individual, partnership, corporation, limited liability company, business trust, joint stock company, trust, unincorporated association, joint venture, firm or other entity, or a government or any political subdivision or agency, department or instrumentality thereof. "PLAN" means an employee benefit plan (other than a Multiemployer Plan) which is (or, in the event that any such plan has been terminated within five years after a transaction described in Section 4069 of ERISA, was) maintained for employees of the Borrower or any ERISA Affiliate and covered by Title IV of ERISA. "PRESCRIBED FORMS" means such duly executed form(s) or statement(s), and in such number of copies, which may, from time to time, be prescribed by law and which, pursuant to applicable provisions of (a) an income tax treaty between the United States and the country of residence of the Bank providing the form(s) or statement(s), (b) the Code, or (c) any applicable rule or regulation under the Code, permit the Borrower to make payments hereunder for the account of such Bank free of deduction or withholding of income or similar taxes (except for any deduction or withholding of income or similar taxes as a result of any change in or in the interpretation of any such treaty, the Code or any such rule or regulation). "PRIME COMMERCIAL LENDING RATE" means that rate of interest from time to time announced by the Bank which is the Administrative Agent at its principal office as its prime rate (or comparable rate, if such Bank does not so designate a "prime rate"), the Prime Commercial Lending Rate to change when and as such prime rate or comparable rate, as the case may be, changes. The Prime Commercial Lending Rate is a reference rate and does not necessarily represent the lowest or best rate actually charged to any customer. Such Bank may make commercial loans or other loans at rates of interest at, above or below the Prime Commercial Lending Rate. For purposes hereof, the principal office of the Administrative Agent, as of the date hereof, is its office located at 712 Main Street, Houston, Texas. "PRINCIPAL SUBSIDIARY" means at any time of determination any Subsidiary having total assets in excess of $100,000,000. For purposes of this definition, total assets shall be determined based on the most recent quarterly or annual financial statements available prior to such determination. At the date hereof, Enron Oil Canada Ltd. is the only Principal Subsidiary. "PRIOR CREDIT FACILITY" means the $300,000,000 Credit Agreement dated as of December 4, 1990, as amended, among the Borrower, the banks named therein and Citibank, N.A., as agent for such banks. -8- "RATING LEVEL" means the applicable category of rating level contained in SCHEDULE I which is based on the rating of the Borrower's senior unsecured long-term debt as classified by Moody's and/or Standard & Poor's and which shall be the highest applicable Rating Level I, Rating Level II, Rating Level III, Rating Level IV, Rating Level V or Rating Level VI, as the case may be, as set forth in SCHEDULE I. "REFERENCE BANKS" means Texas Commerce Bank National Association, The Bank of New York and Bank of America National Trust and Savings Association. "STANDARD & POOR'S" and "S&P" each means Standard & Poor's Corporation. "SUBSIDIARY" means any corporation, partnership, joint venture or other entity of which more than 50% of the outstanding capital stock or other equity interests having ordinary voting power (irrespective of whether or not at the time capital stock or other equity interest of any other class or classes of such corporation, partnership, joint venture or other entity shall or might have voting power upon the occurrence of any contingency) is at the time directly or indirectly owned by the Borrower; PROVIDED, that the definition of "Subsidiary" in EXHIBIT F shall apply in SECTION 5.2(a) only. "TAXES" has the meaning specified in SECTION 2.13(a). "TERMINATION DATE" means January 15, 1998 or the earlier date of termination in whole of the Commitments pursuant to SECTION 2.16 or 6.1. "TERMINATION EVENT" means (a) a "reportable event", as such term is described in Section 4043 of ERISA (other than a "reportable event" not subject to the provision for 30-day notice to the PBGC), or an event described in Section 4062(e) of ERISA, or (b) the withdrawal of the Borrower or any ERISA Affiliate from a Multiple Employer Plan during a plan year in which it was a "substantial employer", as such term is defined in Section 4001(a)(2) of ERISA, or the incurrence of liability by the Borrower or any ERISA Affiliate under Section 4064 of ERISA upon the termination of a Multiple Employer Plan, or (c) the distribution of a notice of intent to terminate a Plan pursuant to Section 4041(a)(2) of ERISA or the treatment of a Plan amendment as a termination under Section 4041 of ERISA, or (d) the institution of proceedings to terminate a Plan by the PBGC under Section 4042 of ERISA, or (e) any other event or condition which might constitute grounds under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan. "TEXAS CREDIT CODE" shall mean Title 79, Revised Civil Statutes of Texas, 1925, as amended. "TOTAL CAPITALIZATION" means, at any time, the sum (without duplication) of (a) Total Debt, and (b) Consolidated Net Worth less any amount thereof attributable to "minority interests" (as defined below). For the purpose of this definition, "minority interests" means any investment or interest of the Borrower in any corporation, partnership or other entity to the -9- extent that the total amount thereof owned by the Borrower (directly or indirectly) constitutes 50% or less of all outstanding interests or investments in such corporation, partnership or entity. "TOTAL DEBT" means, at any time, all Consolidated Debt of the Borrower and its Consolidated Subsidiaries. "WITHDRAWAL LIABILITY" shall have the meaning given such term under Part I of Subtitle E of Title IV of ERISA. 1.2. COMPUTATION OF TIME PERIODS. In this Agreement in the computation of periods of time from a specified date to a later specified date, the word "from" means "from and including" and the words "to" and "until" each means "to but excluding". Unless otherwise indicated, all references to a particular time are references to Houston, Texas time. 1.3. ACCOUNTING TERMS. All accounting terms not specifically defined herein shall be construed in accordance with, and certificates of compliance with financial covenants shall be based on, GAAP; PROVIDED, HOWEVER, the financial statements and reports required pursuant to SECTIONS 5.1(a)(1) and (8) shall be prepared in accordance with generally accepted accounting principles in effect at the time of application thereof except to the extent stated therein. 1.4. MISCELLANEOUS. The words "hereof", "herein" and "hereunder" and words of similar import when used in this Agreement shall refer to this Agreement as a whole and not to any particular provision of this Agreement, and Article, Section, Schedule and Exhibit references are to Articles and Sections of and Schedules and Exhibits to this Agreement, unless otherwise specified. The term "including" shall mean "including, without limitation,". 1.5. RATINGS. A rating, whether public or private, by Standard & Poor's or Moody's shall be deemed to be in effect on the date of announcement or publication by Standard & Poor's or Moody's, as the case may be, of such rating or, in the absence of such announcement or publication, on the effective date of such rating and will remain in effect until the date when any change in such rating is deemed to be in effect. In the event any of the rating categories used by Moody's or Standard & Poor's is revised or designated differently (such as by changing letter designations to different letter designations or to numerical designations), the references herein to such rating shall be changed to the revised or redesignated rating for which the standards are closest to, but not lower than, the standards at the date hereof for the rating which has been revised or redesignated. Long-term debt supported by a letter of credit, guaranty, insurance or other similar credit enhancement mechanism shall not be considered as senior unsecured long-term debt. -10- ARTICLE II AMOUNT AND TERMS OF THE ADVANCES 2.1. THE ADVANCES. Each Bank severally agrees, on the terms and conditions hereinafter set forth, to make one or more Advances to the Borrower from time to time on any Business Day during the period from the date hereof until the Termination Date in an aggregate amount not to exceed at any time outstanding the amount set opposite such Bank's name on the signature pages hereof (as such pages are deemed modified pursuant to this ARTICLE II or SECTION 8.6) (as such amount may be reduced or increased pursuant to SECTION 2.10(e), SECTION 2.15, SECTION 2.16, SECTION 2.17 or SECTION 6.1, such Bank's "COMMITMENT"). Each Borrowing shall be in an aggregate amount not less than $5,000,000 and integral multiples of $1,000,000 above such amount, and shall consist of Advances of the same Type having (in the case of a Borrowing comprised of Adjusted CD Rate Advances or Eurodollar Advances) the same Interest Period, made on the same day by the Banks ratably according to their respective Commitments. Within the limits of each Bank's Commitment, the Borrower may borrow, prepay pursuant to SECTION 2.9 and reborrow under this SECTION 2.1. 2.2. MAKING THE ADVANCES. (a) Each Borrowing shall be made on notice, given not later than 11:00 A.M. (x) in the case of a proposed Borrowing comprised of Eurodollar Advances, at least three Business Days prior to the date of the proposed Borrowing, (y) in the case of a proposed Borrowing comprised of Adjusted CD Rate Advances, at least one Business Day prior to the date of the proposed Borrowing, and (z) in the case of a proposed Borrowing comprised of Base Rate Advances, on the day of the proposed Borrowing, by the Borrower to the Administrative Agent, which shall give to each Bank prompt notice thereof by telecopy. Each such notice of a Borrowing (a "NOTICE OF BORROWING") shall be by telecopy, confirmed immediately in writing, in substantially the form of EXHIBIT B, specifying therein the requested (1) date of such Borrowing, (2) Type of Advances comprising such Borrowing, (3) aggregate amount of such Borrowing, and (4) in the case of a Borrowing comprised of Adjusted CD Rate Advances or Eurodollar Advances, initial Interest Period for each such Advance, PROVIDED that the Borrower may not specify Eurodollar Advances for any Borrowing if, after giving effect to such Borrowing, Eurodollar Advances having more than four different Interest Periods shall be outstanding and the Borrower may not specify Adjusted CD Rate Advances for any Borrowing if, after giving effect to such Borrowing, Adjusted CD Rate Advances having more than four different Interest Periods shall be outstanding. In the case of a proposed Borrowing comprised of Adjusted CD Rate Advances or Eurodollar Advances, the Administrative Agent shall promptly notify each Bank of the applicable interest rate under SECTION 2.5(b) or (c). Each Bank shall, before 11:00 A.M. (2:00 P.M. in the case of a Borrowing comprised of Base Rate Advances) on the date of such Borrowing, make available for the account of its Applicable Lending Office to the Administrative Agent at its Payment Office, in same day funds, such Bank's ratable portion of such Borrowing. After the Administrative Agent's receipt of such funds and upon fulfillment of the applicable conditions set forth in ARTICLE III, the Administrative Agent will make such funds available to the Borrower at the Administrative Agent's aforesaid address. -11- (b) Each Notice of Borrowing shall be irrevocable and binding on the Borrower. In the case of any Borrowing which the related Notice of Borrowing specifies is to be comprised of Adjusted CD Rate Advances or Eurodollar Advances, the Borrower shall, subject to SECTION 8.8, indemnify each Bank against any loss, cost or expense incurred by such Bank as a result of any failure to fulfill on or before the date specified in such Notice of Borrowing for such Borrowing the applicable conditions set forth in ARTICLE III, or to make the Borrowing specified in such Notice of Borrowing on the date specified in such Notice of Borrowing including, without limitation, any loss (excluding loss of anticipated profits), cost or expense incurred by reason of the liquidation or reemployment of deposits or other funds acquired by such Bank to fund the Advance to be made by such Bank as part of such Borrowing when such Advance, as a result of such failure, is not made on such date. (c) Unless the Administrative Agent shall have received notice from a Bank prior to the date of any Borrowing that such Bank will not make available to the Administrative Agent such Bank's ratable portion of such Borrowing, the Administrative Agent may assume that such Bank has made such portion available to the Administrative Agent on the date of such Borrowing in accordance with SUBSECTION (a) of this SECTION 2.2 and the Administrative Agent may, in reliance upon such assumption, make available to the Borrower on such date a corresponding amount. If and to the extent that such Bank shall not have so made such ratable portion available to the Administrative Agent, such Bank and the Borrower severally agree to repay to the Administrative Agent forthwith on demand such corresponding amount together with interest thereon, for each day from the date such amount is made available to the Borrower until the date such amount is repaid to the Administrative Agent, at (1) in the case of the Borrower, the interest rate applicable at the time to Advances comprising such Borrowing and (2) in the case of such Bank, the Federal Funds Rate. If such Bank shall repay to the Administrative Agent such corresponding amount, such amount so repaid shall constitute such Bank's Advance as part of such Borrowing for purposes of this Agreement. (d) The failure of any Bank to make the Advance to be made by it as part of any Borrowing shall not relieve any other Bank of its obligation, if any, hereunder to make its Advance on the date of such Borrowing, but no Bank shall be responsible for the failure of any other Bank to make the Advance to be made by such other Bank on the date of any Borrowing. 2.3. FEES. (a) FACILITY FEE. Subject to SECTION 8.8, the Borrower agrees to pay to each Bank a facility fee on the average daily amount of such Bank's Commitment from the date hereof until, but not including, the Termination Date. The fee is due on the last Business Day of each March, June, September and December during the term of such Bank's Commitment, commencing March 31, 1994, and on the date such Bank's Commitment is terminated. The rate per annum of the facility fee for the period from the date hereof through March 31, 1994 shall be determined as provided in SCHEDULE I based on the Rating Level in effect on the date hereof and for each calendar quarter thereafter shall be determined as provided in SCHEDULE I based on the Rating Level in effect on the first day of such quarter. -12- (b) ADMINISTRATIVE AGENT'S FEE. Subject to SECTION 8.8, the Borrower shall pay to the Administrative Agent such fees as may be separately agreed to by it and the Administrative Agent. 2.4. REPAYMENT. The Borrower shall repay the unpaid principal amount of each Advance owed to each Bank in accordance with the Note to the order of such Bank. All Advances shall be due and payable on the Termination Date. 2.5. INTEREST. Subject to SECTION 8.8, the Borrower shall pay interest on the unpaid principal amount of each Advance owed to each Bank from the date of such Advance until such principal amount shall be paid in full, at the following rates per annum: (a) BASE RATE ADVANCES. During such periods as such Advance is a Base Rate Advance, a rate per annum equal at all times to the Base Rate in effect from time to time, due quarterly on the last Business Day of each March, June, September and December during such periods and on the date such Base Rate Advance shall be Converted or paid in full; PROVIDED that any amount of principal (other than principal of Adjusted CD Rate Advances bearing interest pursuant to the proviso to SECTION 2.5(b) and principal of Eurodollar Advances bearing interest pursuant to the proviso to SECTION 2.5(c)) which is not paid when due (whether at stated maturity, by acceleration or otherwise) shall bear interest, from the date on which such amount is due until such amount is paid in full, due on demand, at a rate per annum equal at all times to 2% per annum above the Base Rate in effect from time to time. (b) ADJUSTED CD RATE ADVANCES. During such periods as such Advance is an Adjusted CD Rate Advance, a rate per annum equal at all times during each Interest Period for such Advance to the sum of the Adjusted CD Rate for such Interest Period for such Advance plus the Applicable Margin per annum for such Interest Period, due on the last day of such Interest Period and, if such Interest Period has a duration of more than 90 days, on the day which occurs during such Interest Period 90 days from the first day of such Interest Period (each Adjusted CD Rate Advance to bear interest from and including the first day of the Interest Period for such Advance to (but not including) the last day of such Interest Period); PROVIDED that any amount of principal of any Adjusted CD Rate Advance which is not paid when due (whether at stated maturity, by acceleration or otherwise) shall bear interest, from the date on which such amount is due until such amount is paid in full, due on demand, at a rate per annum equal at all times to the greater of (x) 2% per annum above the Base Rate in effect from time to time and (y) 2% per annum above the rate per annum required to be paid on such Advance immediately prior to the date on which such amount became due. (c) EURODOLLAR ADVANCES. During such periods as such Advance is a Eurodollar Advance, a rate per annum equal at all times during each Interest Period for such Advance to the sum of the Eurodollar Rate for such Interest Period for such Advance plus the Applicable Margin per annum for such Interest Period, due on the last -13- day of such Interest Period and, if such Interest Period has a duration of more than three months, on the day which occurs during such Interest Period three months from the first day of such Interest Period (each Eurodollar Rate Advance to bear interest from and including the first day of the Interest Period for such Advance to (but not including) the last day of such Interest Period); PROVIDED that any amount of principal of any Eurodollar Advance which is not paid when due (whether at stated maturity, by acceleration or otherwise) shall bear interest, from the date on which such amount is due until such amount is paid in full, due on demand, at a rate per annum equal at all times to the greater of (x) 2% per annum above the Base Rate in effect from time to time and (y) 2% per annum above the rate per annum required to be paid on such Advance immediately prior to the date on which such amount became due. 2.6. ADDITIONAL INTEREST ON EURODOLLAR ADVANCES. If any Bank is required under regulations of the Federal Reserve Board to maintain reserves with respect to liabilities or assets consisting of or including Eurocurrency Liabilities, and if as a result thereof there is an increase in the cost to such Bank of agreeing to make or making, funding or maintaining Eurodollar Advances, the Borrower shall, subject to SECTION 8.8, from time to time, upon demand by such Bank (with a copy of such demand to the Administrative Agent), pay to the Administrative Agent for the account of such Bank additional amounts, as additional interest hereunder, sufficient to compensate such Bank for such increased cost. A certificate in reasonable detail as to the basis for and the amount of such increased cost, submitted to the Borrower and the Administrative Agent by such Bank, shall be conclusive and binding for all purposes, absent manifest error. 2.7. INTEREST RATE DETERMINATION AND PROTECTION. (a) Each Reference Bank agrees to furnish to the Administrative Agent timely information for the purpose of determining each Adjusted CD Rate or Eurodollar Rate, as applicable. If any one or more of the Reference Banks shall not furnish such timely information to the Administrative Agent for the purpose of determining any such interest rate, the Administrative Agent shall determine such interest rate on the basis of timely information furnished by the remaining Reference Banks. (b) The Administrative Agent shall give prompt notice to the Borrower and the Banks of the applicable interest rate determined by the Administrative Agent for purposes of SECTION 2.5(a), (b) or (c), and the applicable rate, if any, furnished by each Reference Bank for the purpose of determining the applicable interest rate under Section 2.5(b) or (c). (c) If fewer than two Reference Banks furnish timely information to the Administrative Agent for determining the Eurodollar Rate for any Eurodollar Advances or the Adjusted CD Rate for any Adjusted CD Rate Advances, (1) the Administrative Agent shall forthwith notify the Borrower and the Banks that the interest rate cannot be determined for such Eurodollar Advances or Adjusted CD Rate Advances, as the case may be, -14- (2) each such Advance will automatically, on the last day of the then existing Interest Period therefor, Convert into a Base Rate Advance (or if such Advance is then a Base Rate Advance, will continue as a Base Rate Advance), and (3) the obligation of the Banks to make, or to Convert Advances into, Adjusted CD Rate Advances or Eurodollar Advances, as the case may be, shall be suspended until the Administrative Agent shall notify the Borrower and the Banks that the circumstances causing such suspension no longer exist. (d) If, with respect to any Adjusted CD Rate Advances or Eurodollar Advances, the Majority Banks notify the Administrative Agent that the applicable interest rate for any Interest Period for such Advances will not adequately reflect the cost to such Majority Banks of making, funding or maintaining their respective Adjusted CD Rate Advances or Eurodollar Advances, as the case may be, for such Interest Period, the Administrative Agent shall forthwith so notify the Borrower and the Banks, whereupon (1) each such Advance will automatically, on the last day of the then existing Interest Period therefor, Convert into a Base Rate Advance (or, if such Advance is then a Base Rate Advance, will continue as a Base Rate Advance), and (2) the obligation of the Banks to make, or to Convert Advances into, Adjusted CD Rate Advances or Eurodollar Advances, as the case may be, shall be suspended until the Administrative Agent shall notify the Borrower and the Banks that the circumstances causing such suspension no longer exist. (e) If the Borrower shall fail to select the duration of any Interest Period for any Adjusted CD Rate Advances or Eurodollar Advances in accordance with the provisions contained in the definition of "Interest Period" in SECTION 1.1, the Administrative Agent will forthwith so notify the Borrower and the Banks and such Advances will automatically, on the last day of the then existing Interest Period therefor, Convert into Base Rate Advances. (f) (1) On the date on which the aggregate unpaid principal amount of Advances comprising any Borrowing of Eurodollar Advances shall be reduced, by payment or prepayment or otherwise, to less than $5,000,000, such Advances shall automatically Convert into Base Rate Advances, and on and after such date the right of the Borrower to Convert such Advances into Eurodollar Advances shall terminate; PROVIDED, HOWEVER, that if and so long as each such Advance shall be of the same Type and have the same Interest Period as Advances comprising another Borrowing or other Borrowings, and the aggregate unpaid principal amount of all such Advances of all such Borrowings shall equal or exceed $5,000,000, the Borrower shall have the right to continue all such Advances as, or to Convert all such Advances into, Advances of such Type having such Interest Period. (2) On the date on which the aggregate unpaid principal amount of Advances comprising any Borrowing of Adjusted CD Rate Advances shall be reduced, by payment or -15- prepayment or otherwise, to less than $5,000,000, such Advances shall automatically Convert into Base Rate Advances, and on and after such date the right of the Borrower to Convert such Advances into Adjusted CD Rate Advances shall terminate; PROVIDED, HOWEVER, that if and so long as each such Advance shall be of the same Type and have the same Interest Period as Advances comprising another Borrowing or other Borrowings, and the aggregate unpaid principal amount of all such Advances of all such Borrowings shall equal or exceed $5,000,000, the Borrower shall have the right to continue all such Advances as, or to Convert all such Advances into, Advances of such Type having such Interest Period. (g) Any Bank may, if it so elects, fulfill its Commitment as to any Eurodollar Advance by causing a branch, foreign or otherwise, or affiliate of such Bank to make such Advance and may transfer and carry such Advance at, to or for the account of any branch office or affiliate of such Bank; PROVIDED that in such event, for the purposes of this Agreement, such Advance shall be deemed to have been made by such Bank and the obligation of the Borrower to repay such Advance shall nevertheless be to such Bank and shall be deemed to be held by such Bank, to the extent of such Advance, for the account of such branch or affiliate. 2.8. VOLUNTARY CONVERSION OF ADVANCES. The Borrower may on any Business Day, upon notice given to the Administrative Agent not later than 11:00 A.M. (x) in the case of a proposed Conversion into Eurodollar Advances, on the third Business Day prior to the date of the proposed Conversion, (y) in the case of a proposed Conversion into Adjusted CD Rate Advances, on the first Business Day prior to the date of the proposed Conversion, and (z) in the case of a proposed Conversion into Base Rate Advances, on the date of the proposed Conversion and subject to the limitations in SECTION 2.2(a) as to the number of permitted Interest Periods and subject to the provisions of SECTIONS 2.7 and 2.11, Convert all Advances of one Type comprising the same Borrowing into Advances of another Type; PROVIDED, HOWEVER, that any Conversion of any Eurodollar Advances shall be made on, and only on, the last day of an Interest Period for such Eurodollar Advances and that any Conversion of any Adjusted CD Rate Advances shall be made on, and only on, the last day of an Interest Period for such Adjusted CD Rate Advances. Each such notice of a Conversion (a "NOTICE OF CONVERSION") shall be by telecopy, confirmed immediately in writing, in substantially the form of EXHIBIT E, and shall, within the restrictions specified above, specify (1) the date of such Conversion, (2) the Advances to be Converted and the Type into which they are to be Converted, and (3) if such Conversion is into Adjusted CD Rate Advances or Eurodollar Advances, the duration of the Interest Period for each such Advance. 2.9. PREPAYMENTS. The Borrower may (x) in respect of Adjusted CD Rate Advances, upon at least one Business Day's notice, (y) in respect of Eurodollar Advances, upon at least three Business Days notice, and, (z) in respect of Base Rate Advances, upon notice by 11:00 A.M. on the day of the proposed prepayment, to the Administrative Agent (which shall promptly notify each Bank) stating the proposed date and aggregate principal amount of the prepayment and the Types of Advances to be prepaid, and in the case of Eurodollar Advances or Adjusted CD Rate Advances, the specific Borrowing or Borrowings pursuant to which made, and if such notice is given the Borrower shall, prepay the outstanding principal amounts of the -16- Advances comprising part of the same Borrowing in whole or ratably in part, together with accrued interest to the date of such prepayment on the principal amount prepaid without premium or penalty; PROVIDED, HOWEVER, that each partial prepayment shall be in an aggregate principal amount not less than $5,000,000, and PROVIDED FURTHER, that if the Borrower prepays any Adjusted CD Rate Advance or any Eurodollar Advance on any day other than the last day of an Interest Period therefor, the Borrower shall compensate the Banks pursuant to SECTION 8.4(b). 2.10. INCREASED COSTS; CAPITAL ADEQUACY, ETC. (a) Subject to SECTION 8.8, if, due to either (1) the introduction of or any change (other than any change by way of imposition or increase of reserve requirements included in the Adjusted CD Rate Reserve Percentage) in or in the interpretation of any law or regulation by any governmental authority, central bank or comparable agency charged with the interpretation or administration thereof or (2) the compliance with any guideline or request from any governmental authority, central bank or comparable agency (whether or not having the force of law), there shall be any increase in the cost to any Bank of agreeing to make or making, funding or maintaining Adjusted CD Rate Advances or Eurodollar Advances (other than increased costs described in SECTION 2.6 or in CLAUSE (c) below), the Borrower shall from time to time, upon demand by such Bank (with a copy of such demand to the Administrative Agent), pay to the Administrative Agent for the account of such Bank additional amounts sufficient to compensate such Bank for such increased cost. A certificate in reasonable detail as to the basis for and the amount of such increased cost, submitted to the Borrower and the Administrative Agent by such Bank, shall be conclusive and binding for all purposes, absent manifest error. Promptly after any Bank becomes aware of any such introduction, change or proposed compliance, such Bank shall notify the Borrower thereof. No Bank shall be permitted to recover increased costs incurred or accrued more than 90 days prior to such notice to the Borrower. (b) If the Borrower so notifies the Administrative Agent within five Business Days after any Bank notifies the Borrower of any increased cost pursuant to the provisions of SECTION 2.10(a), the Borrower shall Convert all Advances of the Type affected by such increased cost of all Banks then outstanding into Advances of another Type in accordance with SECTION 2.8 and, additionally, reimburse such Bank for such increased cost in accordance with SECTION 2.10(a). (c) If any Bank shall have determined that, after the date hereof, the adoption of any applicable law, rule, regulation or treaty regarding capital adequacy, or any change therein, or any change in the interpretation or administration thereof by any governmental authority, central bank or comparable agency charged with the interpretation or administration thereof, or compliance by any Bank (or its lending office) with any request or directive regarding capital adequacy (whether or not having the force of law) of any such authority, central bank or comparable agency (except to the extent such request or directive arises as a result of the individual creditworthiness of such Bank), has or would have the effect of increasing the amount of capital required or expected to be maintained as a result of its Commitment hereunder, such Bank shall have the right to give prompt written notice thereof to the Borrower with a copy to the Administrative Agent, which notice shall show in reasonable detail the calculation of such -17- additional amounts as shall be required to compensate such Bank for the increased cost to such Bank as a result of such increase in capital and shall certify that such costs are generally being charged by such Bank to other similarly situated borrowers under similar credit facilities, which notice shall be conclusive and binding for all purposes, absent manifest error, although the failure to give any such notice shall not, unless such notice fails to set forth the information required above or except as otherwise expressly provided in SECTION 2.10(d), release or diminish any of the Borrower's obligations to pay additional amounts pursuant to SECTION 2.10(d). (d) Each Bank agrees that, upon giving notice specified in SECTION 2.10(c), at the request of the Borrower, it will promptly enter into good faith negotiations with the Borrower with respect to the method of reimbursement for the additional costs specified in such notice. No later than 15 days after the date of the giving of any such notice, and assuming the Bank giving same has made itself available for the aforesaid good faith negotiations, the Borrower shall have the option, to be exercised in writing, to (1) subject to SECTION 8.8, compensate such Bank for the specified additional costs on the basis, if any, negotiated between such Bank and the Borrower or (2) terminate such Bank's Commitment to the extent, and on the terms and conditions, specified in SECTION 2.10(e); PROVIDED that if the Borrower fails to so exercise such option, it shall be deemed to have agreed to reimburse such Bank from time to time on demand the additional costs specified in the Bank's notice delivered pursuant to SECTION 2.10(c). Notwithstanding the foregoing, the Borrower shall not be obligated to reimburse any Bank pursuant to this SECTION 2.10(d) or SECTION 2.10(e) or SECTION 2.18 for any additional costs under SECTION 2.10(c) incurred or accruing more than 90 days prior to the date on which such Bank gave the written notice specified in SECTION 2.10(c). (e) In the event that the Borrower has given notice to a Bank pursuant to SECTION 2.10(d) that it elects to terminate such Bank's Commitment (a copy of which notice shall be sent to the Administrative Agent), such termination shall become effective 15 days thereafter unless such Bank withdraws its request for additional compensation. On the date of the termination of the Commitment of any Bank pursuant to this SECTION 2.10(e), (x) the Borrower shall deliver notice of the effectiveness of such termination to such Bank and to the Administrative Agent, (y) the Borrower shall pay all amounts owed by the Borrower to such Bank under this Agreement or under the Note payable to such Bank (including principal of and interest on the Advances owed to such Bank, accrued facility fees and amounts specified in such Bank's notice delivered pursuant to SECTION 2.10(c) with respect to the period prior to such termination) and (z) upon the occurrence of the events set forth in CLAUSES (x) and (y), such Bank shall cease to be a "Bank" hereunder for all purposes except for rights under SECTIONS 2.6, 2.10, 2.13, 2.18 and 8.4 arising out of events and occurrences before or concurrently with its ceasing to be a "Bank" hereunder. The Borrower may elect to terminate a Bank's Commitment pursuant to SECTION 2.10(d) only if at such time: (1) no Event of Default is then in existence or would be in existence but for requirement that notice be given or time elapse or both; and -18- (2) the Borrower has elected, or is then electing, to terminate the Commitments of all Banks which have made similar requests for increased compensation under this SECTION 2.10, which requests have not been withdrawn, PROVIDED, that requests may be determined by the Borrower to be dissimilar based on the negotiation of materially dissimilar rates of compensation under CLAUSE (1) of SECTION 2.10(d). (f) Each Bank shall use its reasonable efforts (consistent with its internal policies and legal and regulatory restrictions) to select a jurisdiction for its Applicable Lending Office or change the jurisdiction of its Applicable Lending Office, as the case may be, so as to avoid the imposition of any increased costs under this SECTION 2.10 or to eliminate the amount of any such increased cost which may thereafter accrue; PROVIDED that no such selection or change of the jurisdiction for its Applicable Lending Office shall be made if, in the reasonable judgment of such Bank, such selection or change would be disadvantageous to such Bank. 2.11. ILLEGALITY. Notwithstanding any other provision of this Agreement, if the introduction of or any change in or in the interpretation of or compliance with any law or regulation shall make it unlawful, or any governmental authority, central bank or comparable agency shall assert that it is unlawful, for any Bank or its Eurodollar Lending Office to perform its obligations hereunder to make Eurodollar Advances or to continue to fund or maintain Eurodollar Advances hereunder, then, on notice thereof and demand therefor by such Bank to the Borrower through the Administrative Agent, (a) the obligation of the Banks to make Eurodollar Advances and to Convert Advances into Eurodollar Advances shall terminate and (b) the Borrower shall forthwith Convert all Eurodollar Advances of all Banks then outstanding into Advances of another Type in accordance with SECTION 2.8. 2.12. PAYMENTS AND COMPUTATIONS. (a) The Borrower shall make each payment under any Loan Document not later than 11:00 A.M. on the day when due in dollars to the Administrative Agent at its Payment Office in same day funds. The Administrative Agent will promptly thereafter cause to be distributed like funds relating to the payment of principal or interest or facility fees ratably (other than amounts payable pursuant to SECTION 2.6, 2.10, 2.13, 2.18 or 8.4(b)) to the Banks (decreased, as to any Bank, for any taxes withheld in respect of such Bank as contemplated by SECTION 2.13(b)) for the account of their respective Applicable Lending Offices, and like funds relating to the payment of any other amount payable to any Bank to such Bank for the account of its Applicable Lending Office, in each case to be applied in accordance with the terms of this Agreement. (b) All computations of interest based on the Base Rate (except during such times as the Base Rate is determined pursuant to CLAUSE (b) of the definition thereof) and of facility fees shall be made by the Administrative Agent on the basis of a year of 365 or 366 days, as the case may be, and, subject to SECTION 8.8, all computations of interest based on the Adjusted CD Rate, the Eurodollar Rate, the Federal Funds Rate or, during such times as the Base Rate is determined pursuant to CLAUSE (b) of the definition thereof, the Base Rate shall be made by the Administrative Agent, and all computations of interest pursuant to SECTION 2.6 shall be made by a Bank, on the basis of a year of 360 days, in each case for the actual number of days (including -19- the first day but excluding the last day) occurring in the period for which such interest or facility fees are payable. Each determination by the Administrative Agent (or, in the case of SECTION 2.6, by a Bank) of an interest rate hereunder shall be conclusive and binding for all purposes, absent manifest error. (c) Whenever any payment hereunder or under the Notes shall be stated to be due on a day other than a Business Day, such payment shall be made on the next succeeding Business Day, and such extension of time shall in such case be included in the computation of payment of interest or facility fee, as the case may be; PROVIDED, HOWEVER, if such extension would cause payment of interest on or principal of Eurodollar Advances to be made in the next following calendar month, such payment shall be made on the next preceding Business Day. (d) Unless the Administrative Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Banks hereunder that the Borrower will not make such payment in full, the Administrative Agent may assume that the Borrower has made such payment in full to the Administrative Agent on such date and the Administrative Agent may, in reliance upon such assumption, cause to be distributed to each Bank on such due date an amount equal to the amount then due such Bank. If and to the extent the Borrower shall not have so made such payment in full to the Administrative Agent, each Bank shall, subject to SECTION 8.8, repay to the Administrative Agent forthwith on demand such amount distributed to such Bank together with interest thereon, for each day from the date such amount is distributed to such Bank until the earlier of (a) the date such Bank repays such amount to the Administrative Agent and (b) the date two Business Days after the date such amount is so distributed, at the Federal Funds Rate and thereafter until the date such Bank repays such amount to the Administrative Agent at the Federal Funds Rate plus 2%. 2.13. TAXES. (a) Subject to SECTION 8.8, any and all payments by the Borrower hereunder or under the Notes shall be made, in accordance with SECTION 2.12, free and clear of and without deduction for any and all present or future taxes, levies, imposts, deductions, charges, fees, duties or withholdings, and all liabilities with respect thereto, EXCLUDING, in the case of each Bank and the Administrative Agent, (1) taxes imposed on its income, (2) franchise taxes imposed on it by the jurisdiction under the laws of which (or under the laws of a political subdivision of which) such Bank or Administrative Agent (as the case may be) is organized or any political subdivision thereof and, in the case of each Bank, franchise taxes imposed on it by the jurisdiction of such Bank's Applicable Lending Office or any political subdivision thereof and (3) any taxes imposed by the United States of America by means of withholding at the source if and to the extent that such taxes shall be in effect and shall be applicable, to payments to be made to such Bank or the Administrative Agent (all such non-excluded taxes, levies, imposts, deductions, charges, fees, duties, withholdings and liabilities being hereinafter referred to as "TAXES"). Subject to SECTION 8.8, if the Borrower shall be required by law to deduct any Taxes from or in respect of any sum payable hereunder or under any Note to any Bank or the Administrative Agent, (x) the sum payable shall be increased as may be necessary so that after making all required deductions (including deductions applicable to additional sums payable under this SECTION 2.13) such Bank or the Administrative Agent (as the case may be) receives an -20- amount equal to the sum it would have received had no such deductions been made, (y) the Borrower shall make such deductions and (z) the Borrower shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law. (b) Notwithstanding anything to the contrary contained in this Agreement, each of the Borrower and the Administrative Agent shall be entitled, to the extent it is required to do so by law, to deduct or withhold income or other similar taxes imposed by the United States of America from interest, fees or other amounts payable hereunder for the account of any Bank (without the payment by the Borrower of increased amounts to such Bank pursuant to CLAUSE (a) above) other than a Bank (1) which is a domestic corporation (as such term is defined in Section 7701 of the Code) for federal income tax purposes or (2) which has the Prescribed Forms on file with the Borrower and the Administrative Agent for the applicable year to the extent deduction or withholding of such taxes is not required as a result of the filing of such Prescribed Forms, PROVIDED that if the Borrower shall so deduct or withhold any such taxes, it shall provide a statement to the Administrative Agent and such Bank, setting forth the amount of such taxes so deducted or withheld, the applicable rate and any other information or documentation which such Bank or the Administrative Agent may reasonably request for assisting such Bank or the Administrative Agent to obtain any allowable credits or deductions for the taxes so deducted or withheld in the jurisdiction or jurisdictions in which such Bank is subject to tax. (c) In addition, subject to SECTION 8.8, the Borrower agrees to pay any present or future stamp or documentary taxes or any other excise or property taxes, charges or similar levies which arise from any payment made hereunder or under the Notes or from the execution, delivery or registration of, or otherwise with respect to, this Agreement or the Notes (hereinafter referred to as "OTHER TAXES"). (d) The Borrower, to the fullest extent permitted by law, will indemnify each Bank and the Administrative Agent for the full amount of Taxes or Other Taxes (including, without limitation, any Taxes or Other Taxes imposed by any jurisdiction on amounts payable under this SECTION 2.13) paid by such Bank or the Administrative Agent (as the case may be) and any liability (including penalties, interest and expenses) arising therefrom or with respect thereto, (EXPRESSLY INCLUDING SUCH AMOUNTS PAID AS A RESULT OF THE ORDINARY, SOLE OR CONTRIBUTORY NEGLIGENCE OF SUCH BANK OR THE ADMINISTRATIVE AGENT, BUT EXCLUDING SUCH AMOUNTS PAID AS A RESULT OF THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF SUCH BANK OR ADMINISTRATIVE AGENT), whether or not such Taxes or Other Taxes were correctly or legally asserted. This indemnification shall be made within 30 days from the date such Bank or the Administrative Agent (as the case may be) makes written demand therefor. No Bank nor the Administrative Agent shall be indemnified for Taxes or Other Taxes incurred or accrued more than 90 days prior to the date that such Bank or the Administrative Agent notifies the Borrower thereof. (e) Within 30 days after the date of any payment of Taxes by or at the direction of the Borrower, the Borrower will furnish to the Administrative Agent, at its address referred to -21- in SECTION 8.2, the original or a certified copy of a receipt evidencing payment thereof. Should any Bank or the Administrative Agent ever receive any refund, credit or deduction from any taxing authority to which such Bank or the Administrative Agent would not be entitled but for the payment by the Borrower of Taxes as required by this SECTION 2.13 (it being understood that the decision as to whether or not to claim, and if claimed, as to the amount of any such refund, credit or deduction shall be made by such Bank or the Administrative Agent in its sole discretion), such Bank or the Administrative Agent, as the case may be, thereupon shall repay to the Borrower an amount with respect to such refund, credit or deduction equal to any net reduction in taxes actually obtained by such Bank or the Administrative Agent, as the case may be, and determined by such Bank or the Administrative Agent, as the case may be, to be attributable to such refund, credit or deduction. (f) Each Bank shall use its reasonable efforts (consistent with its internal policies and legal and regulatory restrictions) to select a jurisdiction for its Applicable Lending Office or change the jurisdiction of its Applicable Lending Office, as the case may be, so as to avoid the imposition of any Taxes or Other Taxes or to eliminate the amount of any such additional amounts which may thereafter accrue; PROVIDED that no such selection or change of the jurisdiction for its Applicable Lending Office shall be made if, in the reasonable judgment of such Bank, such selection or change would be disadvantageous to such Bank. (g) Without prejudice to the survival of any other agreement of the Borrower hereunder, but subject to the expiration of any applicable statute of limitations, the agreements and obligations of the Borrower contained in this SECTION 2.13 shall survive the payment in full of principal and interest hereunder and under the Notes. 2.14. SHARING OF PAYMENTS, ETC. If any Bank shall obtain any payment (whether voluntary, involuntary, through the exercise of any right of set-off, or otherwise) on account of the Advances made by it (other than pursuant to SECTION 2.6, 2.10, 2.13, 2.18 or 8.4(b)) in excess of its ratable share of payments on account of the Advances obtained by all the Banks, such Bank shall forthwith purchase from the other Banks such participations in the Advances made by them as shall be necessary to cause such purchasing Bank to share the excess payment ratably with each of them, PROVIDED, HOWEVER, that if all or any portion of such excess payment is thereafter recovered from such purchasing Bank, such purchase from each Bank shall be rescinded and such Bank shall repay to the purchasing Bank the purchase price to the extent of its ratable share (according to the proportion of (a) the amount of the participation purchased from such Bank as a result of such excess payment to (b) the total amount of such excess payment) of such recovery together with an amount equal to such Bank's ratable share (according to the proportion of (x) the amount of such Bank's required repayment to (y) the total amount so recovered from the purchasing Bank) of any interest or other amount paid or payable by the purchasing Bank in respect of the total amount so recovered. The Borrower agrees that any Bank so purchasing a participation from another Bank pursuant to this SECTION 2.14 may, to the fullest extent permitted by law, exercise all its rights of payment (including the right of set-off) with respect to such participation as fully as if such Bank were the direct creditor of the Borrower in the amount of such participation. -22- 2.15. INCREASE OF COMMITMENT. The Borrower shall have the right, without the consent of the Banks but subject to the approval of the Administrative Agent (which consent shall not be unreasonably withheld), to effectuate from time to time an increase in the total Commitments under this Agreement by adding to this Agreement one or more commercial banks or other financial institutions (who shall, upon completion of the requirements stated in this SECTION 2.15, constitute Banks hereunder), or by allowing one or more Banks to increase their Commitments hereunder, so that such added and increased Commitments shall equal the increase in Commitments effectuated pursuant to this SECTION 2.15; PROVIDED that (a) no increase in Commitments pursuant to this SECTION 2.15 shall result in the total Commitments exceeding $300,000,000, (b) no Bank's Commitment amount shall be increased without the consent of such Bank, and (c) on the effective date of any such increase in Commitments, there are no amounts outstanding under any of the Notes. The Borrower shall give the Administrative Agent three Business Days' notice of the Borrower's intention to increase the total Commitments pursuant to this SECTION 2.15. Such notice shall specify each new commercial bank or other financial institution, if any, the changes in amounts of Commitments that will result, and such other information as is reasonably requested by the Administrative Agent. Each new commercial bank or other financial institution, and each Bank agreeing to increase its Commitment, shall execute and deliver to the Administrative Agent a document satisfactory to the Administrative Agent pursuant to which it becomes a party hereto or increases its Commitment, as the case may be, which document, in the case of a new commercial bank or other financial institution, shall (among other matters) specify the CD Lending Office, Domestic Lending Office and Eurodollar Lending Office of such new commercial bank or other financial institution. In addition, the Borrower shall execute and deliver a Note in the principal amount of the Commitment of each new commercial bank or other financial institution, or a replacement Note in the principal amount of the increased Commitment of each Bank agreeing to increase its Commitment, as the case may be. Such Notes and other documents of the nature referred to in SECTION 3.1 shall be furnished to the Administrative Agent in form and substance as may be reasonably required by it. Upon execution and delivery of such documents, such new commercial bank or other financial institution shall constitute a "Bank" hereunder with a Commitment as specified therein, or such Bank's Commitment shall increase as specified therein, as the case may be. 2.16. RATABLE REDUCTION OR TERMINATION OF THE COMMITMENTS. The Borrower shall have the right, upon at least three Business Days' notice to the Administrative Agent, to terminate in whole or reduce ratably in part the unused portions of the respective Commitments of the Banks (with the signature pages hereto deemed amended to reflect same); PROVIDED that each partial reduction shall be in the aggregate amount of at least $10,000,000. 2.17. NON-RATABLE REDUCTION OR TERMINATION OF COMMITMENT. The Borrower shall have the right, without the consent of any Bank, but subject to the approval of the Administrative Agent (which consent shall not be unreasonably withheld), to reduce in part or to terminate in whole the Commitment of one or more Banks non-ratably, PROVIDED that (a) on the effective date of any such reduction or termination (w) there are no amounts outstanding under any of the Notes, (x) no Event of Default or event which would constitute an Event of Default but for the requirement that notice be given or time elapse or both, shall have occurred -23- and be continuing, (y) the senior unsecured long-term debt of the Borrower is rated BBB- or better by Standard & Poor's or Baa3 or better by Moody's, and (z) the Borrower shall pay to any Bank whose Commitment is terminated all amounts owed by the Borrower to such Bank under this Agreement (including accrued facility fees), (b) the aggregate amount of each non-ratable reduction shall be at least $10,000,000, and (c) the aggregate amount of all such non-ratable reductions and terminations of Commitments since the date of this Agreement shall not exceed the sum of $25,000,000 plus the aggregate amount of all increases in Commitments effectuated pursuant to SECTION 2.15. The Borrower shall give the Administrative Agent three Business Days' notice of the Borrower's intention to reduce or terminate any Commitment pursuant to this SECTION 2.17. 2.18. REPLACEMENT OF BANK. In the event that any Bank shall claim payment of any increased costs pursuant to SECTION 2.10 or any additional amounts pursuant to SECTION 2.13, the Borrower shall have the right to replace such Bank with another commercial bank or other financial institution; PROVIDED that such replacement commercial bank or other financial institution, (a) if it is not a Bank, shall be reasonably acceptable to the Administrative Agent, (b) shall unconditionally offer in writing (with a copy to the Administrative Agent) to purchase all of such Bank's rights and assume all of such Bank's obligations hereunder and interest in the Advances owing to such Bank and the Note held by such Bank without recourse at the principal amount of such Note plus interest and fees accrued thereon to the date of such purchase on a date therein specified, and (c) shall execute and deliver to the Administrative Agent a document satisfactory to the Administrative Agent pursuant to which such replacement commercial bank or other financial institution becomes a party hereto with a Commitment equal to that of the Bank being replaced, which document, if such replacement commercial bank or other financial institution is not already a Bank, shall (among other matters) specify the CD Lending Office, Domestic Lending Office and Eurodollar Lending Office of such replacement commercial bank or other financial institution. Upon satisfaction of the requirements set forth in the first sentence of this SECTION 2.18, acceptance of such offer to purchase by the Bank to be replaced, payment to such Bank of the purchase price in immediately available funds, and the payment by the Borrower of all requested costs accruing to the date of purchase which the Borrower is obligated to pay under SECTION 8.4 and all other amounts owed by the Borrower to such Bank (other than the principal of and interest on the Advances of such Bank purchased by the replacement commercial bank or other financial institution), the replacement commercial bank or other financial institution shall constitute a "Bank" hereunder with a Commitment as so specified and the Bank being so replaced shall no longer constitute a "Bank" hereunder (with the signature pages being amended to reflect same), except that the rights under SECTIONS 2.6, 2.10, 2.13 and 8.4 of the Bank being so replaced shall continue with respect to arising out of events or occurrences before or concurrently with its ceasing to be a "BANK" hereunder. If, however, (x) a Bank accepts such an offer and such commercial bank or other financial institution fails to purchase such rights and interest on such specified date in accordance with the terms of such offer, the Borrower shall continue to be obligated to pay the increased costs to such Bank pursuant to SECTION 2.10 or the additional amounts pursuant to SECTION 2.13, as the case may be, or (y) the Bank proposed to be replaced fails to accept such purchase offer, the Borrower shall -24- not be obligated to pay to such Bank such increased costs or additional amounts incurred or accrued from and after the date of such purchase offer. ARTICLE III CONDITIONS TO ADVANCES 3.1. INITIAL CONDITIONS PRECEDENT. The obligation of each Bank to make Advances pursuant to the terms and conditions of this Agreement is subject to the conditions precedent that the Administrative Agent shall have received evidence satisfactory to it that the Prior Credit Facility shall have been terminated and all amounts owing thereunder repaid in full and the Administrative Agent shall have received the following, each dated on or before the date of the initial Advance hereunder, in form and substance satisfactory to the Administrative Agent: (a) The executed Notes payable to the order of the Banks, respectively. (b) Certified copies of the resolutions of the Board of Directors of the Borrower approving this Agreement, each Note and each Notice of Borrowing, and of all documents evidencing other necessary corporate action and governmental approvals, if any, with respect to each such Loan Document and certified copies of the restated certificate of incorporation and bylaws of the Borrower. (c) A certificate of the Secretary or an Assistant Secretary of the Borrower certifying the names and true signatures of the officers of the Borrower authorized to sign each Loan Document to which it is a party and the other documents to be delivered hereunder. (d) A favorable opinion of Vinson & Elkins L.L.P., counsel for the Borrower, to be delivered to, and for the benefit of, the Banks and the Administrative Agent, at the express instruction of the Borrower, substantially in the form of EXHIBIT C and as to such other matters as any Bank through the Administrative Agent may reasonably request. (e) A favorable opinion of Dennis M. Ulak, Vice President and General Counsel of the Borrower, to be delivered to, and for the benefit of, the Banks and the Administrative Agent, at the express instruction of the Borrower, in substantially the form of EXHIBIT D and as to such other matters as any Bank through the Administrative Agent may reasonably request. (f) A Notice of Entire Agreement and DTPA Waiver, executed by the Borrower and, to the limited extent set forth therein, its general counsel. 3.2. ADDITIONAL CONDITIONS PRECEDENT TO EACH ADVANCE. The obligation of each Bank to make any Advance shall be subject to the additional conditions precedent that on the -25- date of such Advance (a) the following statements shall be true (and each of the giving of the applicable Notice of Borrowing and the acceptance by the Borrower of the proceeds of such Advance shall constitute a representation and warranty by the Borrower that on the date of such Advance such statements are true): (1) The representations and warranties contained in SECTION 4.1 of this Agreement are correct on and as of the date of such Advance, before and after giving effect to such Advance and the Borrowing of which such Advance is a part and to the application of the proceeds therefrom, as though made on and as of such date, and (2) No event has occurred and is continuing, or would result from such Advance or the Borrowing of which such Advance is a part or from the application of the proceeds therefrom, which constitutes an Event of Default or would constitute an Event of Default but for the requirement that notice be given or time elapse or both; and (b) the Administrative Agent shall have received the Notice of Borrowing required by SECTION 2.2 and such other approvals, opinions or documents as any Bank through the Administrative Agent may reasonably request. ARTICLE IV REPRESENTATIONS AND WARRANTIES 4.1. REPRESENTATIONS AND WARRANTIES OF THE BORROWER. The Borrower represents and warrants to the Banks as follows: (a) The Borrower and each Principal Subsidiary are corporations duly incorporated, validly existing and in good standing under the laws of their respective jurisdictions of incorporation. The Borrower and each Principal Subsidiary have all corporate powers and all material governmental licenses, authorizations, consents and approvals required in each case to carry on its business as now conducted. (b) The execution, delivery and performance by the Borrower of each Loan Document to which it is or will be a party are within the Borrower's corporate powers, have been duly authorized by all necessary corporate action of the Borrower, require, in respect of the Borrower, no action by or in respect of, or filing with, any governmental body, agency or official and do not contravene, or constitute a default under, any provision of law or regulation (including Regulation X issued by the Federal Reserve Board) applicable to the Borrower or Regulation U issued by the Federal Reserve Board or the restated certificate of incorporation or by-laws of the Borrower or any judgment, injunction, order, decree or material ("material" for the purposes of this representation meaning creating a liability of $50,000,000 or more) agreement binding upon the -26- Borrower or result in the creation or imposition of any lien, security interest or other charge or encumbrance on any asset of the Borrower or any of its Subsidiaries. (c) This Agreement and each Note are, and each other Loan Document to which the Borrower is or will be a party, when executed and delivered in accordance with this Agreement will be, the legal, valid and binding obligation of the Borrower enforceable against the Borrower in accordance with its terms, except as the enforceability thereof may be limited by the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting creditors' rights generally and by general principles of equity. (d) The audited consolidated balance sheet of the Borrower and its Subsidiaries as of December 31, 1992 and the related audited consolidated statements of income, cash flows and changes in shareholders' equity accounts for the fiscal year then ended and the unaudited consolidated balance sheet of the Borrower and its Subsidiaries as of September 30, 1993, and the related unaudited consolidated statements of income, cash flows and changes in shareholders' equity accounts for the fiscal quarter then ended, certified by the chief financial or accounting officer of the Borrower, copies of which have been delivered to each of the Banks, fairly present, in conformity with GAAP except as otherwise expressly noted therein, the consolidated financial position of the Borrower and its Subsidiaries as of such dates and their consolidated results of operations and changes in financial position for such fiscal periods, subject (in the case of the unaudited balance sheet and statements) to changes resulting from audit and normal year-end adjustments. (e) Since December 31, 1992 there has been no material adverse change in the consolidated financial position or consolidated results of operations of the Borrower and its Subsidiaries, considered as a whole. (f) Except as disclosed in the Borrower's Form 10-K for the year ended December 31, 1992 or the Borrower's Form 10-Q for each of the quarters ended March 31, 1993, June 30, 1993 and September 30, 1993, which were delivered to the Banks prior to the date hereof, there is no action, suit or proceeding pending against the Borrower or any of its Subsidiaries, or to the knowledge of the Borrower threatened against the Borrower or any of its Subsidiaries, before any court or arbitrator or any governmental body, agency or official in which there is a reasonable possibility of an adverse decision which could materially adversely affect the consolidated financial position or consolidated results of operations of the Borrower and its Subsidiaries taken as a whole or which in any manner draws into question the validity of this Agreement or any other Loan Document to which the Borrower is or will be a party. (g) No Termination Event has occurred or is reasonably expected to occur with respect to any Plan for which an Insufficiency in excess of $50,000,000 exists. Neither the Borrower nor any ERISA Affiliate has received any notification (or has knowledge of any reason to expect) that any Multiemployer Plan is in reorganization or -27- has been terminated, within the meaning of Title IV of ERISA, for which a Withdrawal Liability in excess of $50,000,000 exists. (h) United States federal income tax returns of the Borrower and its Subsidiaries have been examined and closed through the fiscal year ended December 31, 1987. The Borrower and its Subsidiaries have filed or caused to be filed all United States federal income tax returns and all other material domestic tax returns which to the knowledge of the Borrower are required to be filed by them and have paid or provided for the payment, before the same become delinquent, of all taxes due pursuant to such returns or pursuant to any assessment received by the Borrower or any Subsidiary, other than those taxes contested in good faith by appropriate proceedings. The charges, accruals and reserves on the books of the Borrower and its Subsidiaries in respect of taxes are, in the opinion of the Borrower, adequate to the extent required by GAAP. (i) Neither the Borrower nor any Subsidiary is an "investment company" within the meaning of the Investment Company Act of 1940, as amended. (j) Neither the Borrower nor any Principal Subsidiary is a "holding company", a "subsidiary company" of a "holding company", an "affiliate" of a "holding company", or an "affiliate" of a "subsidiary company" of a "holding company", in each case as such terms are defined in the Public Utility Holding Company Act of 1935, as amended. (k) Following application of the proceeds of each Advance, not more than 25 percent of the value of the assets (both of the Borrower only and of the Borrower and its Subsidiaries on a consolidated basis), which are subject to any arrangement with the Administrative Agent or any Bank (herein or otherwise) whereby the Borrower's or any Subsidiary's right or ability to sell, pledge or otherwise dispose of assets is in any way restricted, will be margin stock (within the meaning of Regulation U issued by the Federal Reserve Board). ARTICLE V COVENANTS OF THE BORROWER 5.1. AFFIRMATIVE COVENANTS. The Borrower covenants and agrees that so long as any Note shall remain unpaid or any Bank shall have any Commitment hereunder, the Borrower will, unless the Majority Banks shall otherwise consent in writing: (a) REPORTING REQUIREMENTS. Furnish to each Bank: (1) (A) promptly after the sending or filing thereof, a copy of each of the Borrower's reports on Form 8-K (or any comparable form), (B) promptly after -28- the filing or sending thereof, and in any event within 75 days after the end of each of the first three fiscal quarters of each fiscal year of the Borrower, a copy of the Borrower's report on Form 10-Q (or any comparable form) for such quarter, which report will include the Borrower's quarterly unaudited consolidated financial statements as of the end of and for such quarter, and (C) promptly after the filing or sending thereof, and in any event within 135 days after the end of each fiscal year of the Borrower, a copy of the Borrower's annual report which it sends to its public security holders, and a copy of the Borrower's report on Form 10-K (or any comparable form) for such year, which annual report will include the Borrower's annual audited consolidated financial statements as of the end of and for such year; (2) simultaneously with the delivery of each of the annual or quarterly reports referred to in CLAUSE (1) above, a certificate of the chief financial officer or the chief accounting officer of the Borrower in a form acceptable to the Administrative Agent (x) setting forth in reasonable detail the calculations required to establish whether the Borrower was in compliance with the requirements of SECTION 5.2(b) on the date of the financial statements contained in such report, and (y) stating whether there exists on the date of such certificate any Event of Default or event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default, and, if so, setting forth the details thereof and the action which the Borrower has taken and proposes to take with respect thereto; (3) as soon as is possible and in any event within five days after a change in, or issuance of, any rating of any of the Borrower's senior unsecured long-term debt by Standard & Poor's or Moody's which causes a change in the applicable Rating Level, notice of such change; (4) as soon as possible and in any event within five days after an executive officer of the Borrower having obtained knowledge thereof, notice of the occurrence of any Event of Default or any event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default, continuing on the date of such notice, and a statement of the chief financial officer of the Borrower setting forth details of such Event of Default or event and the action which the Borrower has taken and proposes to take with respect thereto; (5) as soon as possible and in any event (A) within 30 Business Days after the Borrower or any ERISA Affiliate knows or has reason to know that any Termination Event described in CLAUSE (a) of the definition of Termination Event with respect to any Plan for which an Insufficiency in excess of $50,000,000 exists, has occurred and (B) within 10 Business Days after the Borrower or any ERISA Affiliate knows or has reason to know that any other Termination Event with respect to any Plan for which an Insufficiency in excess of $50,000,000 -29- exists, has occurred or is reasonably expected to occur, a statement of the chief financial officer or chief accounting officer of the Borrower describing such Termination Event and the action, if any, which the Borrower or such ERISA Affiliate proposes to take with respect thereto; (6) promptly and in any event within five Business Days after receipt thereof by the Borrower or any ERISA Affiliate, copies of each notice received by the Borrower or any ERISA Affiliate from the PBGC stating its intention to terminate any Plan for which an Insufficiency in excess of $50,000,000 exists or to have a trustee appointed to administer any Plan for which an Insufficiency in excess of $50,000,000 exists; (7) promptly and in any event within five Business Days after receipt thereof by the Borrower or any ERISA Affiliate from the sponsor of a Multiemployer Plan, a copy of each notice received by the Borrower or any ERISA Affiliate indicating liability in excess of $50,000,000 incurred or expected to be incurred by the Borrower or any ERISA Affiliate in connection with (A) the imposition of a Withdrawal Liability by a Multiemployer Plan, (B) the determination that a Multiemployer Plan is, or is expected to be, in reorganization within the meaning of Title IV of ERISA, or (C) the termination of a Multiemployer Plan within the meaning of Title IV of ERISA; and (8) such other information respecting the Consolidated financial position or Consolidated results of operations (including an annual report or reports on oil and gas reserves of the Borrower and its Subsidiaries), of the Borrower that any Bank through the Administrative Agent may from time to time reasonably request. (b) COMPLIANCE WITH LAWS, ETC. Comply, and cause each of its Subsidiaries to comply, with all applicable laws, rules, regulations and orders to the extent noncompliance therewith would have a material adverse effect on the Borrower and its Subsidiaries taken as a whole, such compliance to include, without limitation, the paying before the same become delinquent of all taxes, assessments and governmental charges imposed upon it or upon its property except to the extent contested in good faith by appropriate proceedings. (c) USE OF PROCEEDS. Use the proceeds of each Advance for general corporate purposes. However, no part of the proceeds of the Advances shall be used for the purpose of purchasing or carrying margin stock within the meaning of Regulation U issued by the Federal Reserve Board. (d) MAINTENANCE OF INSURANCE. Maintain, and cause each of the Principal Subsidiaries to maintain, insurance with responsible and reputable insurance companies or associations in such amounts and covering such risks as is usually carried by -30- companies engaged in similar businesses and owning similar properties as the Borrower or such Principal Subsidiary, PROVIDED, that self-insurance by the Borrower or any such Principal Subsidiary shall not be deemed a violation of this covenant to the extent that companies engaged in similar businesses and owning similar properties as the Borrower or such Principal Subsidiary self-insure. The Borrower may maintain the Principal Subsidiaries' insurance on behalf of them. (e) PRESERVATION OF CORPORATE EXISTENCE, ETC. Preserve and maintain, and cause each of the Principal Subsidiaries to preserve and maintain, its corporate existence, rights (charter and statutory), and franchises; PROVIDED, HOWEVER, that this SECTION 5.1(e) shall not apply to any transactions permitted by SECTION 5.2(c) or (d) and shall not prevent the termination of existence, rights and franchises of any Principal Subsidiary pursuant to any merger or consolidation to which such Principal Subsidiary is a party, and PROVIDED, FURTHER, that the Borrower or any Principal Subsidiary shall not be required to preserve any right or franchise if the Borrower or such Principal Subsidiary shall determine that the preservation thereof is no longer desirable in the conduct of the business of the Borrower or such Principal Subsidiary, as the case may be, and that the loss thereof is not disadvantageous in any material respect to the Banks. (f) VISITATION RIGHTS. At any reasonable time and from time to time, after reasonable notice, permit the Administrative Agent or any of the Banks or any agents or representatives thereof to examine the records and books of account of, and visit the properties of, the Borrower and any of the Principal Subsidiaries and to discuss the affairs, finances and accounts of the Borrower and any of the Principal Subsidiaries with any of the officers or directors of the Borrower. 5.2. NEGATIVE COVENANTS. So long as any Note shall remain unpaid or any Bank shall have any Commitment hereunder, the Borrower will not at any time, without the written consent of the Majority Banks: (a) NEGATIVE PLEDGE. Fail to perform and observe any term, covenant or agreement contained in SECTION 1007 of the Indenture (as modified for purposes hereof as set forth in this SECTION 5.2). For purposes of this SECTION 5.2(a), SECTION 1007 and the definitions of all terms defined in the Indenture and used in or otherwise applicable to such SECTION 1007 are set forth on EXHIBIT F and are hereby incorporated in this Agreement by reference as if such provisions and definitions were set forth in full herein; PROVIDED, however, that solely for purposes of this SECTION 5.2, the word "SECURITIES" used in the Indenture shall mean the Notes, the word "COMPANY" used therein shall mean the Borrower, the phrase "SECTION 1007" used therein shall mean this SECTION 5.2(a), the word "TRUSTEE" as used therein shall mean the Administrative Agent, the phrase "Board of Directors" used in the Indenture shall mean the management of the Borrower, SECTION 301 of the Indenture shall not apply to any Note, and the phrase "SO LONG AS ANY OF THE SECURITIES ARE OUTSTANDING" used therein shall mean so long as any Note shall remain unpaid or any Bank shall have any Commitment hereunder. -31- (b) TOTAL DEBT TO CAPITALIZATION. Have a ratio of (i) Total Debt to (ii) Total Capitalization greater than 50%. (c) DISPOSITION OF ASSETS. Lease, sell, transfer or otherwise dispose of, voluntarily or involuntarily, all or substantially all of its assets. (d) MERGERS, ETC. Merge or consolidate with or into, any Person, unless (1) the Borrower is the survivor or (2) the surviving Person, if not the Borrower, is organized under the laws of the United States or a state thereof and assumes all obligations of the Borrower under the Agreement, PROVIDED, in each case that both immediately before and after giving effect to such proposed transaction, no Event of Default or event which, with the giving of notice or the lapse of time, or both, would constitute an Event of Default exists, or would exist or result. (e) COMPLIANCE WITH ERISA. (1) Terminate, or permit any ERISA Affiliate to terminate, any Plan so as to result in any liability in excess of $50,000,000 of the Borrower or any ERISA Affiliate to the PBGC, or (2) permit circumstances which give rise to a Termination Event described in CLAUSES (b), (d) or (e) of the definition of Termination Event with respect to a Plan so as to result in any liability in excess of $50,000,000 of the Borrower or any ERISA Affiliate to the PBGC. ARTICLE VI EVENTS OF DEFAULT 6.1. EVENTS OF DEFAULT. If any of the following events ("EVENTS OF DEFAULT") shall occur and be continuing: (a) The Borrower shall fail to pay (1) any principal on any Note when due and payable or (2) any interest on any Note for more than five days after such interest becomes due and payable or (3) the facility fee set forth in SECTION 2.3(a) for more than 15 days after such fee becomes due and payable; or (b) Any representation or warranty made by the Borrower (or any of its officers) (including representations and warranties deemed made pursuant to SECTION 3.2) under or in connection with any Loan Document shall prove to have been incorrect in any material respect when made or deemed made and such materiality is continuing; or (c) The Borrower shall fail to perform or observe any term, covenant or agreement contained in SECTION 5.2 or shall fail to perform or observe any other term, covenant or agreement contained in any Loan Document on its part to be performed or observed if, in the case of such other term, covenant or agreement, such failure shall -32- remain unremedied for 30 days after written notice thereof shall have been given to the Borrower by the Administrative Agent at the request of any Bank; or (d) The Borrower or any Principal Subsidiary shall (1) fail to pay any principal of or premium or interest on any Debt (other than Debt described in CLAUSE (c) of the definition of Debt) which is outstanding in the principal amount of at least $50,000,000 in the aggregate, of the Borrower or such Principal Subsidiary (as the case may be), when the same becomes due and payable (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and such failure shall continue after the applicable grace period, if any, specified in the agreement or instrument relating to such Debt; or any other event shall occur or condition shall exist under any agreement or instrument relating to any such Debt and shall continue after the applicable grace period, if any, specified in such agreement or instrument, if the effect of such event or condition is to accelerate the maturity of such Debt; or any such Debt shall be declared to be due and payable, or required to be prepaid (other than by a regularly scheduled required prepayment or as a result of the giving of notice of a voluntary prepayment), prior to the stated maturity thereof, or (2) with respect to Debt described in CLAUSE (c) of the definition of Debt, fail to pay any such Debt which is outstanding in the principal amount of at least $50,000,000 in the aggregate, of the Borrower or such Principal Subsidiary (as the case may be), when the same becomes due and payable, and such failure shall continue after the applicable grace period, if any, specified in the agreement or instrument relating to such Debt; or (e) The Borrower or any Principal Subsidiary shall generally not pay its debts as such debts become due, or shall admit in writing its inability to pay its debts generally, or shall make a general assignment for the benefit of creditors; or any proceeding shall be instituted by or against the Borrower or any Principal Subsidiary seeking to adjudicate it as bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief or composition of it or its debts under any law relating to bankruptcy, insolvency or reorganization or relief of debtors, or seeking the entry of an order for relief or the appointment of a receiver, trustee or other similar official for it or for any substantial part of its property and, in the case of any such proceeding instituted against it (but not instituted by it), shall remain undismissed or unstayed for a period of 60 days; or the Borrower or any Principal Subsidiary shall take any corporate action to authorize any of the actions set forth above in this SUBSECTION (e); or (f) Any judgment, decree or order for the payment of money in excess of $50,000,000 shall be rendered against the Borrower or any Principal Subsidiary and shall remain unsatisfied and either (1) enforcement proceedings shall have been commenced by any creditor upon such judgment, decree or order or (2) there shall be any period longer than (i) 30 consecutive days or (ii) such longer period as allowed by applicable law during which a stay of enforcement of such judgment, decree or order, by reason of a pending appeal or otherwise, shall not be in effect; or -33- (g) Any Termination Event as defined in CLAUSES (b), (d) or (e) of the definition thereof with respect to a Plan shall have occurred and, 30 days after notice thereof shall have been given to the Borrower by the Administrative Agent, (1) such Termination Event shall still exist and (2) the sum (determined as of the date of occurrence of such Termination Event) of the liabilities to the PBGC resulting from all such Termination Events is equal to or greater than $100,000,000; or (h) The Borrower or any ERISA Affiliate shall have been notified by the sponsor of a Multiemployer Plan that it has incurred Withdrawal Liability to such Multiemployer Plan in an amount which, when aggregated with all other amounts required to be paid to Multiemployer Plans in connection with Withdrawal Liabilities (determined as of the date of such notification), exceeds $100,000,000 or requires payments exceeding $50,000,000 in any year; or (i) The Borrower or any ERISA Affiliate shall have been notified by the sponsor of a Multiemployer Plan that such Multiemployer Plan is in reorganization or is being terminated, within the meaning of Title IV of ERISA, if as a result of such reorganization or termination the aggregate annual contributions of the Borrower and its ERISA Affiliates to all Multiemployer Plans which are then in reorganization or being terminated have been or will be increased over the amounts contributed to such Multiemployer Plans for the respective plan years which include the date hereof by an amount exceeding $50,000,000 in the aggregate; then, and in any such event, the Administrative Agent (1) shall at the request, or may with the consent, of the Majority Banks, by notice to the Borrower, declare the obligation of each Bank to make Advances to be terminated, whereupon the same shall forthwith terminate, and (2) shall at the request, or may with the consent, of the Majority Banks, by notice to the Borrower, declare the principal balance of the Notes, all interest accrued thereon and all other accrued amounts payable under this Agreement to be forthwith due and payable, whereupon the principal balance of the Notes, all such accrued interest and all such accrued amounts shall become and be forthwith due and payable, without presentment, demand, protest, notice of intent to accelerate or further notice of any kind, all of which are, to the extent permitted by law, hereby expressly WAIVED by the Borrower; PROVIDED, HOWEVER, that in the event of an actual or deemed entry of an order for relief with respect to the Borrower under the Bankruptcy Code, (A) the obligation of each Bank to make its Advances shall automatically be terminated and (B) the principal balance of the Notes, all such accrued interest and all such accrued amounts shall automatically become and be due and payable, without presentment, demand, protest, notice of intent to accelerate or any notice of any kind, all of which are, to the extent permitted by law, hereby expressly WAIVED by the Borrower. -34- ARTICLE VII THE ADMINISTRATIVE AGENT 7.1. AUTHORIZATION AND ACTION. Each Bank hereby appoints and authorizes the Administrative Agent to take such action as agent on its behalf and to exercise such powers under the Loan Documents as are delegated to the Administrative Agent, by the terms hereof and thereof, together with such powers as are reasonably incidental thereto. As to any matters not expressly provided for by the Loan Documents (including enforcement or collection of the Notes), the Administrative Agent shall not be required to exercise any discretion or take any action, but shall be required to act or to refrain from acting (and shall be fully protected in so acting or refraining from acting) upon the instructions of the Majority Banks, and such instructions shall be binding upon all Banks and all holders of Notes; PROVIDED, HOWEVER, that the Administrative Agent shall not be required to take any action which exposes the Administrative Agent to personal liability or which is contrary to any Loan Document or applicable law and shall not be required to initiate or conduct any litigation or other proceedings. The Administrative Agent agrees to give to each Bank prompt notice of each notice given to it by the Borrower pursuant to the terms of this Agreement. 7.2. ADMINISTRATIVE AGENT'S RELIANCE, ETC. Neither the Administrative Agent nor any of its directors, officers, agents or employees shall be liable for any action taken or omitted to be taken by it or them under or in connection with any Loan Document, except for its or their own gross negligence or willful misconduct. The duties of the Administrative Agent shall be mechanical and administrative in nature; the Administrative Agent shall not have, by reason of this Agreement or any other Loan Document a fiduciary relationship in respect of any Bank or the holder of any Note; and nothing in this Agreement or any other Loan Document, expressed or implied, is intended or shall be so construed as to impose upon the Administrative Agent any obligations in respect of this Agreement or any other Loan Document except as expressly set forth herein. Without limitation of the generality of the foregoing, the Administrative Agent: (a) may treat the payee of any Note as the holder thereof until the Administrative Agent receives written notice of the assignment or transfer thereof signed by such payee and in form satisfactory to the Administrative Agent; (b) may consult with legal counsel (including counsel for the Borrower), independent public accountants and other experts selected by it and shall not be liable for any action taken or omitted to be taken in good faith by it in accordance with the advice of such counsel, accountants or experts; (c) makes no warranty or representation to any Bank and shall not be responsible to any Bank for any statements, warranties or representations made in or in connection with any Loan Document; (d) shall not have any duty to ascertain or to inquire as to the performance or observance of any of the terms, covenants or conditions of any Loan Document on the part of the Borrower or to inspect the property (including the books and records) of the Borrower and shall not be deemed to have knowledge of an Event of Default or of any event which with the giving of notice or the lapse of time or both would be an Event of Default (other than nonpayment of principal of or interest on the Notes or any facility fee) unless it has received from a Bank or the Borrower a notice specifying such default and stating that it is an "NOTICE OF DEFAULT"; (e) shall not be responsible -35- to any Bank for the due execution, legality, validity, enforceability, genuineness, sufficiency or value of any Loan Document or any other instrument or document furnished pursuant hereto; and (f) shall incur no liability under or in respect of any Loan Document by acting upon any notice, consent, certificate or other instrument or writing (which may be by telecopier, telegram, cable or telex) believed by it to be genuine and signed or sent by the proper party or parties. 7.3. ADMINISTRATIVE AGENT AND ITS AFFILIATES. With respect to its Commitment, the Advances made by it and the Note issued to it, the Bank which is also the Administrative Agent shall have the same rights and powers under the Loan Documents as any other Bank and may exercise the same as though it were not the Administrative Agent; and the term "Bank" or "Banks" shall, unless otherwise expressly indicated, include the Bank serving as the Administrative Agent in its individual capacity. The Bank serving as the Administrative Agent and its affiliates may accept deposits from, lend money to, act as trustee under indentures of, and generally engage in any kind of business with, the Borrower, any of the Subsidiaries and any Person who may do business with or own securities of the Borrower or any Subsidiary, all as if such Bank were not the Administrative Agent and without any duty to account therefor to the Banks. 7.4. BANK CREDIT DECISION. Each Bank acknowledges that it has, independently and without reliance upon the Administrative Agent or any other Bank and based on the financial statements referred to in SECTION 4.1(d) and such other documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement. Each Bank also acknowledges that it will, independently and without reliance upon the Administrative Agent or any other Bank and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under this Agreement and the other Loan Documents. The Administrative Agent shall not have any duty or responsibility, either initially or on a continuing basis, to provide any Bank or the holder of any Note with any credit or other information with respect thereto, whether coming into its possession before the making of the Advances or at any time or times thereafter. The Administrative Agent shall not be responsible to any Bank or the holder of any Note for any recitals, statements, information, representations or warranties herein or in any document, certificate or other writing delivered in connection herewith or for the execution, effectiveness, genuineness, validity, enforceability, collectibility, priority or sufficiency of this Agreement or any other Loan Document or the financial condition of the Borrower or be required to make any inquiry concerning either the performance or observance of any of the terms, provisions or conditions of this Agreement or any other Loan Document, or the financial condition of the Borrower or the existence or possible existence of any Event of Default or event of which would constitute an Event of Default but for the requirement that notice be given or time elapse or both. 7.5. CERTAIN RIGHTS OF THE ADMINISTRATIVE AGENT. If the Administrative Agent shall request instructions from all of the Banks (in the case of matters specified in the proviso of SECTION 8.1) or the Majority Banks (in all other cases) with respect to any act or action (including failure to act) in connection with this Agreement or any other Loan Document, the -36- Administrative Agent shall be entitled to refrain from such act or taking such action unless and until the Administrative Agent shall have received instructions from all of the Banks or the Majority Banks, as the case may be; and it shall not incur liability to any Person by reason of so refraining. Without limiting the foregoing, no Bank or the holder of any Note shall have any right of action whatsoever against the Administrative Agent as a result of its acting or refraining from acting hereunder or under any other Loan Document in accordance with the instructions of the Majority Banks or all of the Banks, as the case may be. Furthermore, except for action expressly required of the Administrative Agent hereunder, the Administrative Agent shall in all cases be fully justified in failing or refusing to act hereunder unless it shall be specifically indemnified to its satisfaction by the Banks against any and all liability and expense which may be incurred by it by reason of taking or continuing to take any such action. 7.6. HOLDERS. Any request, authority or consent of any Person who, at the time of making such request or giving such authority or consent, is the holder of any Note shall be conclusive and binding on any subsequent holder, transferee, assignee or indorsee, as the case may be, of such Note or of any Note or Notes issued in exchange therefor. 7.7. INDEMNIFICATION. The Banks agree to indemnify the Administrative Agent (to the extent not reimbursed by the Borrower), ratably according to the respective principal amounts of the Notes then held by each of them (or if no principal of the Notes is at the time outstanding or if any principal of the Notes is held by Persons which are not Banks, ratably according to the respective amounts of their Commitments then existing, or, if no such principal amounts are then outstanding and no Commitments are then existing, ratably according to the respective amounts of the Commitments existing immediately prior to the termination thereof), from and against any and all liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs, expenses or disbursements of any kind or nature whatsoever which may be imposed on, incurred by, or asserted against the Administrative Agent in any way relating to or arising out of any of the Loan Documents or any action taken or omitted by the Administrative Agent under the Loan Documents EXPRESSLY INCLUDING ANY SUCH LIABILITY, OBLIGATION, LOSS, DAMAGE, PENALTY, ACTION, JUDGMENT, SUIT, COST, EXPENSE OR DISBURSEMENT ATTRIBUTABLE TO THE ORDINARY, SOLE OR CONTRIBUTORY NEGLIGENCE OF SUCH INDEMNIFIED PARTY; PROVIDED THAT NO BANK SHALL BE LIABLE FOR ANY PORTION OF SUCH LIABILITIES, OBLIGATIONS, LOSSES, DAMAGES, PENALTIES, ACTIONS, JUDGMENTS, SUITS, COSTS, EXPENSES OR DISBURSEMENTS RESULTING FROM THE ADMINISTRATIVE AGENT'S GROSS NEGLIGENCE OR WILLFUL MISCONDUCT. IT IS THE INTENT OF THE BANKS THAT THE ADMINISTRATIVE AGENT SHALL, TO THE EXTENT PROVIDED IN THIS SECTION 7.7, BE INDEMNIFIED FOR ITS ORDINARY, SOLE OR CONTRIBUTORY NEGLIGENCE. Without limitation of the foregoing, each Bank agrees to reimburse the Administrative Agent promptly upon demand for such Bank's ratable share of any reasonable out-of-pocket expenses (including reasonable counsel fees) incurred by the Administrative Agent in connection with the preparation, execution, delivery, administration, modification, amendment or enforcement (whether through negotiations, legal proceedings or otherwise) of, or legal advice in respect of -37- rights or responsibilities under, the Loan Documents, or any of them, to the extent that the Administrative Agent is not reimbursed for such expenses by the Borrower. 7.8. RESIGNATION BY THE ADMINISTRATIVE AGENT. (a) The Administrative Agent may resign from the performance of all its functions and duties hereunder and under the other Loan Documents at any time by giving 15 Business Days' prior written notice to the Borrower and the Banks. Such resignation shall take effect upon the appointment of a successor Administrative Agent pursuant to CLAUSES (b) and (c) below or as otherwise provided below. (b) Upon any such notice of resignation, the Majority Banks shall have the right to appoint a successor Administrative Agent which shall be a commercial bank or trust company reasonably acceptable to the Borrower. (c) If a successor to a resigning Administrative Agent shall not have been so appointed within such 15 Business Day period, the resigning Administrative Agent, with the consent of the Borrower (which consent will not be unreasonably withheld), shall have the right to then appoint a successor Administrative Agent who shall serve as Administrative Agent until such time, if any, as the Majority Banks appoint a successor Administrative Agent as provided above. (d) If no successor Administrative Agent has been appointed pursuant to CLAUSE (b) or (c) above and shall have accepted such appointment by the 20th Business Day after the date such notice of resignation was given by the resigning Administrative Agent, the resigning Administrative Agent's resignation shall become effective and the Banks shall thereafter perform all the duties of the resigning Administrative Agent hereunder and under any other Loan Document until such time, if any, as the Majority Banks appoint a successor Administrative Agent as provided above. ARTICLE VIII MISCELLANEOUS 8.1. AMENDMENTS, ETC. No amendment or waiver of any provision of any Loan Document, nor consent to any departure by the Borrower therefrom, shall in any event be effective unless the same shall be in writing and signed by the Majority Banks, and then such waiver or consent shall be effective only in the specific instance and for the specific purpose for which given; PROVIDED, HOWEVER, that no amendment, waiver or consent shall, unless in writing and signed by all the Banks, do any of the following: (a) waive any of the conditions specified in ARTICLE III, (b) increase the Commitments of the Banks or subject the Banks to any additional obligations, except as provided in SECTION 2.15, (c) forgive or reduce the principal of, or interest on, the Notes or any fees or other amounts payable hereunder, (d) postpone any date fixed for any payment of principal of, or interest on, the Notes or any fees or other amounts payable hereunder, (e) take any action which requires the consent of all the Banks pursuant to the terms -38- of any Loan Document, (f) change the percentage of the Commitments or of the aggregate unpaid principal amount of the Notes which shall be required for the Banks or any of them to take any action under any Loan Document or (g) amend this SECTION 8.1; and PROVIDED, FURTHER, that no amendment, waiver or consent shall, unless in writing and signed by the Administrative Agent in addition to the Banks required above to take such action, affect the rights or duties of the Administrative Agent under any Loan Document. 8.2. NOTICES, ETC. All notices and other communications provided for hereunder shall be in writing (including telecopier communication) and mailed, telecopied or delivered, if to the Borrower, at its address or telecopier number set forth below: Enron Oil & Gas Company 1400 Smith Street Houston, Texas 77002 Attention: Kurt S. Huneke Vice President, Finance and Treasurer Telecopier No.: 713-646-3422 if to any Bank, at its Domestic Lending Office; if to the Administrative Agent, at its address or telecopier number set forth below: Texas Commerce Bank National Association 712 Main Street Houston, Texas 77002 Attention: Mr. James R. McBride Energy Group Telecopier No.: 713-216-4117 or, as to the Borrower or the Administrative Agent, at such other address as shall be designated by such party in a written notice to the other parties and, as to each other party, at such other address as shall be designated by such party in a written notice to the Borrower and the Administrative Agent. All such notices and communications shall be effective, if mailed, two Business Days after deposit in the mails; if sent by overnight courier, one Business Day after delivery to the courier company; and if sent by telecopier, when received by the receiving telecopier equipment, respectively; PROVIDED, HOWEVER, that (a) notices and communications to the Administrative Agent shall not be effective until received by the Administrative Agent and (b) telecopied notices received by any party after its normal business hours (or on a day other than a Business Day) shall be effective on the next Business Day. -39- 8.3. NO WAIVER; REMEDIES. No failure on the part of any Bank or the Administrative Agent to exercise, and no delay in exercising, and no course of dealing with respect to, any right under any Loan Document shall operate as a waiver thereof; nor shall any single or partial exercise of any such right preclude any other or further exercise thereof or the exercise of any other right. The remedies provided in the Loan Documents are cumulative and not exclusive of any remedies provided by law or in equity. 8.4. COSTS, EXPENSES AND TAXES. (a) Subject to SECTION 8.8, the Borrower agrees to pay on demand (1) all reasonable costs and expenses in connection with the preparation, execution, delivery, administration, modification and amendment of the Loan Documents and the other documents to be delivered under the Loan Documents, including the reasonable fees and out-of-pocket expenses of one law firm as counsel for the Administrative Agent with respect to preparation, execution and delivery of the Loan Documents and the satisfaction of the matters referred to in SECTION 3.1, and (2) all legal and other costs and expenses, if any, of the Administrative Agent and each Bank in connection with the enforcement (whether through negotiations, legal proceedings or otherwise) of the Loan Documents and the other documents to be delivered under the Loan Documents or incurred in connection with any workout, restructuring or bankruptcy. (b) If any payment or purchase of principal of, or Conversion of, any Adjusted CD Rate Advance or Eurodollar Advance is made other than on the last day of an Interest Period relating to such Advance, as a result of a payment, purchase or Conversion pursuant to SECTIONS 2.7(f), 2.8, 2.9, 2.10, 2.11, 2.13 or 2.18 or acceleration of the maturity of the Notes pursuant to SECTION 6.1 or for any other reason, the Borrower, subject to SECTION 8.8, shall, upon demand by any Bank (with a copy of such demand to the Administrative Agent), pay to the Administrative Agent for the account of such Bank any amounts required to compensate such Bank for any additional losses, costs or expenses which it may reasonably incur as a result of such payment, purchase or Conversion, including, without limitation, any loss (excluding loss of anticipated profits), cost or expense incurred by reason of the liquidation or reemployment of deposits or other funds acquired by such Bank to fund or maintain such Advance. A certificate in reasonable detail as to the basis for and the amount of such loss, costs or expense, submitted to the Borrower and the Administrative Agent by such Bank, shall be conclusive and binding for all purposes, absent manifest error. (c) The Borrower agrees, to the fullest extent not prohibited by law, to indemnify and hold harmless the Administrative Agent and each Bank and each of their respective directors, officers, employees and agents from and against any and all claims, damages, liabilities and expenses (including, without limitation, reasonable fees and disbursements of counsel and claims, damages, liabilities and expenses relating to environmental matters) for which any of them may become liable or which may be incurred by or asserted against the Administrative Agent or such Bank or any such director, officer, employee or agent other than by the Administrative Agent or another Bank or any of their respective successors or assigns), in each case in connection with or arising out of or by reason of any investigation, litigation, or proceeding, whether or not the Administrative Agent or such Bank or any such -40- director, officer, employee or agent is a party thereto, arising out of, related to or in connection with this Agreement or any other Loan Document or any transaction in which any proceeds of all or any part of the Advances are applied (EXPRESSLY INCLUDING ANY SUCH CLAIM, DAMAGE, LIABILITY OR EXPENSE ATTRIBUTABLE TO THE ORDINARY, SOLE OR CONTRIBUTORY NEGLIGENCE OF SUCH INDEMNIFIED PARTY, BUT EXCLUDING ANY SUCH CLAIM, DAMAGE, LIABILITY OR EXPENSE ATTRIBUTABLE TO THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF SUCH INDEMNIFIED PARTY). IT IS THE INTENT OF THE PARTIES HERETO THAT THE ADMINISTRATIVE AGENT AND EACH BANK, AND THEIR RESPECTIVE DIRECTORS, OFFICERS, EMPLOYEES AND AGENTS, SHALL, TO THE EXTENT PROVIDED IN THIS SECTION 8.4(c), BE INDEMNIFIED FOR THEIR OWN ORDINARY, SOLE OR CONTRIBUTORY NEGLIGENCE. 8.5. RIGHT OF SET-OFF. Upon (a) the occurrence and during the continuance of any Event of Default and (b) the making of the request or the granting of the consent specified by SECTION 6.1 to authorize the Administrative Agent to declare the Notes due and payable pursuant to the provisions of SECTION 6.1, each Bank is hereby authorized at any time and from time to time, to the fullest extent permitted by law, to set off and apply any and all deposits (general or special, time or demand, provisional or final) at any time held and other indebtedness at any time owing by such Bank to or for the credit or the account of the Borrower against any and all of the obligations of the Borrower now or hereafter existing under this Agreement and the Note held by such Bank, irrespective of whether or not the Administrative Agent or such Bank shall have made any demand under this Agreement or such Note and although such obligations may be unmatured. Each Bank agrees promptly to notify the Borrower after any such set-off and application made by such Bank; PROVIDED that the failure to give such notice shall not affect the validity of such set-off and application. The rights of each Bank under this SECTION 8.5 are in addition to other rights and remedies (including, without limitation, other rights of set-off) which such Bank may have. 8.6. BINDING EFFECT; ASSIGNMENTS; PARTICIPATIONS. (a) This Agreement shall become effective when it shall have been executed by the Borrower and the Administrative Agent and when the Administrative Agent shall have, as to each Bank, either received a copy of a signature page hereof executed by such Bank or been notified by such Bank that such Bank has executed it and thereafter shall be binding upon and inure to the benefit of and be enforceable by the Borrower, the Administrative Agent and each Bank and their respective successors and assigns, except that the Borrower shall not have the right to assign its rights hereunder or any interest herein without the express prior written consent of the Banks (other than an assignment effectuated by a merger or consolidation permitted by SECTION 5.2(e) to the surviving Person referred to therein). Each Bank may assign to one or more banks or other entities all or any part of, or may grant participations to one or more banks or other entities in accordance with applicable law in or to all or any part of, the Advances owing to such Bank and the Note held by such Bank and any such Bank's continuing obligations with respect thereto, and to the extent of any such assignment or participation (unless otherwise stated therein) the assignee or purchaser of such assignment or participation shall, to the fullest extent permitted -41- by law, have the same rights to payment hereunder and under such Note as it would have if it were such Bank hereunder; PROVIDED that (x) such Bank's obligations under this Agreement, including its Commitment, shall remain unchanged, such Bank shall remain solely responsible for the performance thereof, such Bank shall remain the holder of any such Note for all purposes under this Agreement, and the Borrower, the other Banks and the Administrative Agent shall continue to deal solely and directly with such Bank in connection with such Bank's rights and obligations under this Agreement; (y) no such assignee or participant shall be entitled to receive any greater payment pursuant to SECTIONS 2.6, 2.10 and 2.13 than such Bank would have been entitled to receive with respect to the rights assigned or participated except as a result of circumstances arising after the date of such assignment or participation to the extent that such circumstances affect other Banks and participants generally; and (z) no Bank shall assign or grant a participation that conveys to the assignee or participant the right to vote or consent under this Agreement, other than the right to vote upon or consent to (1) any increase in the amount of such Bank's Commitment; (2) any reduction of the principal amount of, or interest to be paid on, such Bank's Advance or Advances or Note; (3) any reduction of the facility fee; or (4) any postponement of the due date in respect of any amounts owed to such Bank under any Loan Document. (b) Notwithstanding anything to the contrary in SECTION 8.6(a), in accordance with applicable law (x) any Bank may assign a portion of its Commitment and its rights and obligations to one or more Banks, and (y) any Bank may assign a portion, in an amount of at least $10,000,000 of its Commitment (PROVIDED such assignment does not result in the remaining Commitment of the assigning Bank being less than $10,000,000), and its rights and obligations hereunder to another commercial bank or financial institution, in the case of assignments pursuant to CLAUSE (y) above with prior written consents of the Administrative Agent and the Borrower, which consents shall not be unreasonably withheld, each of which assignees pursuant to CLAUSE (y) to become a party to this Agreement as a Bank by executing and delivering to the Administrative Agent an amendment to this Agreement or a supplemental agreement with the assigning Bank, which amendment or supplemental agreement shall be in form and substance reasonably satisfactory to the Administrative Agent and shall (among other matters) specify the CD Lending Office, the Domestic Lending Office and the Eurodollar Lending Office of such commercial bank or financial institution; PROVIDED that, in the case of each such assignment, (A) at such time the signature pages to this Agreement shall be deemed to be modified to reflect the Commitments of such assignee Bank and of the existing Banks, (B) the Borrower shall issue new Notes to such assignee Bank and to the assigning Bank to reflect the revised Commitments and (C) the Administrative Agent shall receive at the time of such assignment, from the assigning or assignee Bank, a non-refundable assignment fee of $2,500. To the extent of any assignment pursuant to this SECTION 8.6(b), the assigning Bank shall be relieved of its obligations hereunder with respect to its assigned Commitment. (c) In addition to the assignments and participations permitted under SUBSECTIONS (a) and (b) of this SECTION 8.6, any Bank may assign, as collateral or otherwise, any of its rights (including rights to payments of principal of and/or interest on the Notes) under any Loan Document to any Federal Reserve Bank without notice to or consent of the Borrower or -42- the Administrative Agent; PROVIDED, that no such assignment under this SUBSECTION (c) shall release the assigning Bank from its obligations hereunder. 8.7. GOVERNING LAW; ENTIRE AGREEMENT. THIS AGREEMENT AND THE NOTES SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. This Agreement, the Notes, the other Loan Documents and any fee letter to the Administrative Agent signed by the Borrower constitute the entire understanding among the parties hereto with respect to the subject matter hereof and supersede any prior agreements, written or oral, with respect thereto. 8.8. INTEREST. The parties to this Agreement intend to strictly comply with all applicable laws, including applicable usury laws. Accordingly, the provisions of this SECTION 8.8 shall govern and control over every other provision of any Loan Document which conflicts or is inconsistent with this SECTION 8.8, even if such provision declares that it controls. As used in this SECTION 8.8, the term "interest" includes the aggregate of all charges, fees, benefits or other compensation which constitute interest under applicable law; PROVIDED that, to the maximum extent permitted by applicable law, (a) any non-principal payment shall be characterized as an expense or as compensation for something other than the use, forbearance or detention of money, and not as interest and (b) all interest at any time contracted for, taken, reserved, charged or received shall be amortized, prorated, allocated and spread during the full term of the Advances and the Commitments. In no event shall the Borrower or any other Person be obligated to pay, or the Administrative Agent or any Bank have any right or privilege to reserve, receive or retain, (x) any interest in excess of the maximum amount of nonusurious interest permitted under the laws of the State of Texas or the applicable laws (if any) of the United States or of any other state or (y) total interest in excess of the amount which the Administrative Agent or such Bank could lawfully have contracted for, reserved, received, retained or charged had the interest been calculated for the full term of the Advances at the Highest Lawful Rate. On each day, if any, that the interest rate (the "STATED RATE") called for under any Loan Document exceeds the Highest Lawful Rate, the rate at which interest shall accrue shall automatically be fixed by operation of this sentence at the Highest Lawful Rate for that day, and shall remain fixed at the Highest Lawful Rate for each day thereafter until the total amount of interest accrued equals the total amount of interest which would have accrued if there were no such ceiling rate as is imposed by this sentence. Thereafter, interest shall accrue at the Stated Rate unless and until the Stated Rate again exceeds the Highest Lawful Rate when the provisions of the immediately preceding sentence shall again automatically operate to limit the interest accrual rate. The daily interest rates to be used in calculating interest at the Highest Lawful Rate shall be determined by dividing the applicable Highest Lawful Rate per annum by the number of days in the calendar year for which such calculation is being made. None of the terms and provisions contained in any Loan Document which directly or indirectly relate to interest shall ever be construed without reference to this SECTION 8.8, or be construed to create a contract to pay for the use, forbearance or detention of money at an interest rate in excess of the Highest Lawful Rate. If the term of any of the Notes is shortened by reason of acceleration of maturity or by reason of any required or permitted prepayment, and if for that (or any other) reason the Administrative Agent or any Bank at any time, including the stated maturity, is owed -43- or receives (and/or has received) interest in excess of interest calculated at the Highest Lawful Rate, then and in any such event all of any such excess interest shall be cancelled automatically as of the date of such acceleration, prepayment or other event which produces the excess, and, if such excess interest has been paid to the Administrative Agent or such Bank, it shall be credited PRO TANTO against the then outstanding principal balance of the Borrower's obligations to the Administrative Agent or such Bank, effective as of the date or dates when the event occurs which causes it to be excess interest, until such excess is exhausted or all of such principal has been fully paid and satisfied, whichever occurs first, and any remaining balance of such excess shall be promptly refunded to its payor. 8.9. CAPTIONS. Captions and SECTION headings appearing herein are included solely for convenience of reference and are not intended to affect the interpretation of any provision of this Agreement. 8.10. CONFIDENTIALITY. Each Bank agrees that it will use reasonable efforts not to disclose without the prior consent of the Borrower (other than to its employees, auditors or counsel, to another Bank, or to such Bank's own holding or parent company and its affiliates, in each case if the disclosing Bank or its holding or parent company in its sole discretion determines that any such party should have access to such information) any information with respect to the Borrower or its Subsidiaries which is furnished pursuant to this Agreement or any other Loan Document and which is designated by the Borrower to the Banks in writing as confidential; PROVIDED that any Bank may disclose any such information (a) as has become generally available to the public, (b) as may be required or appropriate in any report, statement or testimony submitted to any municipal, state or federal regulatory body having or claiming to have jurisdiction over such Bank or to the Federal Reserve Board or the FDIC or similar organizations (whether in the United States or elsewhere), (c) as may be required or appropriate in response to any summons or subpoena or in connection with any litigation, (d) in order to comply with any law, order, regulation or ruling applicable to such Bank, and (e) to the prospective transferee in connection with any contemplated transfer of any of the Notes or any interest therein by such Bank; PROVIDED, FURTHER, that such prospective transferee executes an agreement with the Borrower containing provisions substantially identical to those contained in this SECTION 8.10. 8.11. SURVIVAL; TERM; REINSTATEMENT. In addition to the other provisions of this Agreement expressly stated to survive the termination of this Agreement, the obligations of the Borrower under SECTIONS 2.6, 2,10, 2.13, 2.18 and 8.4 and the last sentence of this SECTION 8.11 and the obligations of the Banks under SECTION 8.10 shall survive the termination of this Agreement. The Borrower agrees that if at any time all or any part of any payment previously applied by any Bank to any Advance or other sum hereunder is or must be returned by or recovered from such Bank for any reason (including the order of any bankruptcy court), the Loan Documents shall automatically be reinstated to the same effect as if the prior application had not been made, and the Borrower hereby agrees to indemnify such Bank against, and to save and hold such Bank harmless from, any required return by or recovery from such Bank of any such payment. -44- 8.12. SEVERABILITY. Whenever possible, each provision of the Loan Documents shall be interpreted in such manner as to be effective and valid under applicable law. If any provision of any Loan Document shall be invalid, illegal or unenforceable in any respect under any applicable law, the validity, legality and enforceability of the remaining provisions of such Loan Document shall not be affected or impaired thereby. 8.13. CHAPTER 15 NOT APPLICABLE. Chapter 15 of the Texas Credit Code shall not apply to any Loan Document or to any Commitment or Advance, nor shall any Loan Document be governed by or be subject to the provisions of such Chapter 15 in any manner whatsoever. 8.14. EXECUTION IN COUNTERPARTS. This Agreement may be executed in any number of counterparts and by different parties hereto in separate counterparts, each of which when so executed shall be deemed to be an original and all of which taken together shall constitute one and the same agreement. 8.15. WAIVER OF NOTICE. Each Bank that is a party to the Prior Credit Facility hereby WAIVES (both in its capacity as a "Bank" thereunder and, if applicable, in its capacity as "Agent" thereunder), to the extent permitted by law, the requirement of notice of termination contemplated by SECTION 2.04(b) of the Prior Credit Facility. -45- IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be executed by their respective officers thereunto duly authorized, as of the date first above written. BORROWER: ENRON OIL & GAS COMPANY By: Walter C. Wilson Senior Vice President and Chief Financial Officer ADMINISTRATIVE AGENT: TEXAS COMMERCE BANK NATIONAL ASSOCIATION COMMITMENT $30,000,000 By: James R. McBride Senior Vice President BANK OF AMERICA NATIONAL TRUST AND SAVINGS ASSOCIATION COMMITMENT $10,000,000 By: Name: John R. Madden Title: Vice President THE BANK OF NEW YORK COMMITMENT $20,000,000 By: Name: Daniel T. Gates Title: Vice President THE BANK OF NOVA SCOTIA COMMITMENT $10,000,000 By: Name: A. S. Norsworthy Title: Assistant Agent CREDIT LYONNAIS CAYMAN ISLAND BRANCH COMMITMENT $10,000,000 By: Name: R. A. Touis Title: Authorized Signatory CREDIT SUISSE COMMITMENT $10,000,000 By: Name: Geoffrey M. Craig Title: Member of Senior Management By: Name: Kristinn R. Kristinsson Title: Associate THE FIRST NATIONAL BANK OF CHICAGO COMMITMENT $10,000,000 By: Name: Helen A. Carr Title: Vice President SCHEDULE I (BASIS POINTS)
Level I Level II Level III Basis for Pricing If the Borrower's If the Borrower's If the Borrower's Senior Unsecured Long Senior Unsecured Long Senior Unsecured Long Term Debt is rated A Term Debt is rated Term Debt is rated BBB or better by S&P or A2 BBB+ or better by S&P and Baa2 by or better by Moody's. by S&P or Baa1 or Moody's. better by Moody's. Facility Fee 12.5 15.0 17.5 *Unused* Cost 12.5 15.0 17.5 p.a. If Facility usage is below 50%: Eurodollar + 20.0 20.0 20.0 Base Rate + 0 0 0 CD + 32.5 32.5 32.5 *Used* 32.5 35.0 37.5 Eurodollar + If Facility usage is at or above 50%: Eurodollar + 25.0 30.0 30.0 Base Rate + 0 0 0 CD + 37.5 42.5 42.5 *Used* 37.5 45.0 47.5 Eurodollar + Level IV Level V Level VI Basis for Pricing If the Borrower's If the Borrower's If the Borrower's Senior Unsecured Long Senior Unsecured Long Senior Unsecured Long Term Debt is rated BBB Term Debt is rated BBB Term Debt is rated BB+ by S&P by S&P and Baa3 by or lower or Baa3 by Moody's. by S&P and Ba1 or Moody's. lower by Moody's or is not rated by either S&P or Moody's. Facility Fee 20.0 25.0 35.0 *Unused* Cost 20.0 25.0 35.0 p.a. If Facility usage is below 50%: Eurodollar + 40.0 45.0 65.0 Base Rate + 0 0 0 CD + 52.5 57.5 77.5 *Used* 60.0 70.0 100.0 Eurodollar + If Facility usage is at or above 50%: Eurodollar + 50.0 55.0 75.0 Base Rate + 0 0 0 CD + 62.5 67.5 87.5 *Used* 70.0 80.0 110.0 Eurodollar + * Facility Fee plus spread over Eurodollar
SCHEDULE II Applicable Lending Offices TEXAS COMMERCE BANK NATIONAL ASSOCIATION Domestic and Eurodollar Lending Offices: 712 Main Street Houston, Texas 77002 Attention: Manager, Energy Group Fax: 713/216-4117 Telex: 166-053 (Answerback: TCB HOU) ABA #113000609 For Credit to Account #20730 Attn: Loan Syndicate Services Gale Manning Reference: Enron Oil & Gas (Borrrowings, paydowns, commitment reductions, fees, etc.) THE BANK OF NEW YORK EURODOLLAR LENDING OFFICE 101 Barclay Street ABA#021000018 Eurodollar Cayman Funding Area Libor Acct #803-3140-992 Reference: Enron Oil & Gas (ref., fees, int., prin.) DOMESTIC LENDING OFFICE: Commercial Loan Servicing Dept. Account #BBK #111-556 Reference: Enron Oil & Gas (ref., fees, int., prin.) THE BANK OF NOVA SCOTIA DOMESTIC AND EURODOLLAR LENDING OFFICES The Bank of Nova Scotia 600 Peachtree Street N.E., Suite 2700 Atlanta, Georgia 30308 Phone: 404/877-1500 Fax: 404/888-8998 CREDIT LYONAIS CAYMAN ISLAND BRANCH DOMESTIC AND EURODOLLAR LENDING OFFICES: Mr. David Dodd Credit Lyonnais Cayman Island Branch Houston Office, 1000 Louisiana, Suite 5360 Houston, Texas 77002 THE FIRST NATIONAL BANK OF CHICAGO DOMESTIC AND EURODOLLAR LENDING OFFICES: One First National Plaza Chicago, Illinois 60670 Attn: Bill Laird Phone: 312/732-5635 Fax: 312/732-4840 BANK OF AMERICA NATIONAL TRUST AND SAVINGS ASSOCIATION DOMESTIC AND EURODOLLAR LENDING OFFICES: Bank of America National Trust and Savings Association ABA #121000358, Account #1233183980 1850 Gateway Boulevard, 4th Floor Concord, California 94520 Attn: Camille Gibby, Acct. Admin. Phone: 510/675-7759 Fax: 510/675-7531 CREDIT SUISSE DOMESTIC AND EURODOLLAR LENDING OFFICES: Credit Suisse Credit Administration Attn: Hazel Leslie Tower 49-12 East 49th Street New York, New York 10017 Phone: 212/238-5218 Fax: 212/238-5245 SCHEDULE II PROMISSORY NOTE EXHIBIT A U.S. $ Houston, Texas , 19 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of U.S. dollars (U.S. $__________) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: Title: ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
NOTICE OF BORROWING EXHIBIT B Texas Commerce Bank National Association, as Administrative Agent 712 Main Street Houston, Texas 77002 {Date} Attention: Manager, Energy Group 5 TCB-N 86 Ladies and Gentlemen: The undersigned, Enron Oil & Gas Company, refers to the Revolving Credit Agreement, dated as of March 11, 1994 (such Revolving Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT", the terms defined therein being used herein as therein defined), among the undersigned, certain Banks parties thereto and Texas Commerce Bank National Association, as Administrative Agent for said Banks, and hereby gives you notice, irrevocably, pursuant to SECTION 2.2 of the Credit Agreement that the undersigned hereby requests a Borrowing under the Credit Agreement, and in that connection sets forth below the information relating to such Borrowing (the "PROPOSED BORROWING") as required by SECTION 2.2(a) of the Credit Agreement: (1) The Business Day of the Proposed Borrowing is ________________, 199___. (2) The type of Advances comprising the Proposed Borrowing is {Base Rate Advances} {Adjusted CD Rate Advances} {Eurodollar Advances}. (3) The aggregate amount of the Proposed Borrowing is $___________. *{(4) The initial Interest Period for each Advance made as part of the Proposed Borrowing is _______ (days) (months).} The undersigned hereby certifies that the following statements are true on the date hereof, and will be true on the date of the Proposed Borrowing: *To be included for a Proposed Borrowing comprised of Adjusted CD Rate Advances or Eurodollar Advances. (A) the representations and warranties contained in SECTION 4.1 of the Credit Agreement are correct, before and after giving effect to the Proposed Borrowing and to the application of the proceeds therefrom, as though made on and as of such date; and (B) no event has occurred and is continuing, or would result from such Proposed Borrowing or from the application of the proceeds therefrom, which constitutes an Event of Default or would constitute an Event of Default but for the requirement that notice be given or time elapse or both. Very truly yours, ENRON OIL & GAS COMPANY By: Title: EXHIBIT C Vinson & Elkins L.L.P. 2500 First City Tower 1001 Fannin Houston, Texas 77002-6760 {Date} To each of the Banks parties to the Revolving Credit Agreement dated as of March 11, 1994 among Enron Oil & Gas Company, said Banks and Texas Commerce Bank National Association, as Administrative Agent for said Banks and to such Administrative Agent Re: ENRON OIL & GAS COMPANY Ladies and Gentlemen: This opinion is furnished to you pursuant to Section 3.1(d) of the Revolving Credit Agreement, dated as of March 11, 1994 (the "Credit Agreement"), among Enron Oil & Gas Company (the "Borrower"), the Banks parties thereto and Texas Commerce Bank National Association, as Administrative Agent for said Banks. Except as otherwise defined herein, terms defined in the Credit Agreement are used herein as therein defined. We have acted as counsel for the Borrower in connection with the preparation, execution, delivery and effectiveness of the Credit Agreement. In that connection, we have examined: (1) The Credit Agreement; and (2) The other documents furnished by the Borrower pursuant to the conditions precedent set forth in Section 3.1 of the Credit Agreement. We have also examined the originals, or copies certified to our satisfaction, of the documents listed in a certificate of the Senior Vice President and Chief Financial Officer of the Borrower dated the date hereof (the "Officer's Certificate"), certifying that the documents listed in such certificate include all of the material (meaning for purposes of this opinion those creating a monetary liability of $50,000,000 or more) indentures, loan or credit agreements, receivables sale or financing agreements, lease financing agreements, capital leases, mortgages, security agreements, bonds and notes (except bonds and notes issued pursuant to the aforesaid indentures and loan or credit agreements), and guaranties of any such obligations, to which the Borrower is subject and to the effect that there are no orders, writs, judgments, awards, injunctions or decrees, which affect or purport to affect the Borrower's right to borrow money or the Borrower's obligations under the Loan Documents. In addition, we have (i) investigated such questions of law and (ii) relied on such certificates from officers and representatives of the Borrower and from public officials, as we have deemed necessary or appropriate for the purposes of this opinion. In rendering the opinions herein set forth, we have assumed (i) the due authorization, execution and delivery of each document referred to in clauses (1) and (2) of the third paragraph of this opinion by all parties to such documents and that each such document is valid, binding and enforceable (subject to limitations on enforceability of the types referred to in paragraphs (a) and (b) below) against the parties thereto other than the Borrower, (ii) the legal capacity of natural persons, (iii) the genuineness of all signatures, (iv) the authenticity of all documents submitted to us as originals and (v) the conformity to original documents of all documents submitted to us as copies. Based upon the foregoing and upon such investigation as we have deemed necessary, we are of the following opinion: 1. No authorization, approval or other action by, and no notice to or filing with, any governmental authority or regulatory body is required to be made or obtained by the Borrower for the execution, delivery and performance by the Borrower of each Loan Document. 2. The execution, delivery and performance by the Borrower of each Loan Document does not contravene (i) any provision of law or regulation (including, without limitation, Regulation X issued by the Federal Reserve Board) applicable to the Borrower or of Regulation U issued by the Federal Reserve Board, or (ii) any contractual or legal restriction contained in any material document listed in the Officer's Certificate. 3. The Credit Agreement and the Notes constitute the legal, valid and binding obligations of the Borrower enforceable against the Borrower in accordance with their terms. 4. The Borrower is not an "investment company" within the meaning of the Investment Company Act of 1940, as amended. 5. Neither the Borrower nor any Principal Subsidiary is a "holding company" or a "subsidiary company" of a "holding company", in each case as such terms are defined in the Public Utility Holding Company Act of 1935, as amended, or regulated pursuant to such Act or the rules and regulations promulgated thereunder or any order or interpretation of the Securities and Exchange Commission or its staff issued pursuant thereto. The opinions set forth above are subject to the following qualifications: (a) Our opinion in paragraph 3 above is subject, as to enforceability, to the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or similar law affecting creditors' rights generally. (b) Our opinion in paragraph 3 above is subject, as to enforceability, to the effect of general principles of equity (regardless of whether considered in a proceeding in equity or at law), including without limitation, concepts of materiality, reasonableness, good faith and fair dealing, and also to the possible unavailability of specific performance or injunctive relief. Such principles of equity are of general application, and in applying such principles a court, among other things, might not allow a creditor to accelerate maturity of a debt upon the occurrence of a default deemed immaterial or might decline to order the Borrower to perform covenants. In rendering the opinions expressed in paragraphs 1, 2 and 3 above, we have relied upon the opinions stated in paragraphs 1 and 2 (so far as such paragraph 2 relates to the corporate powers of, and due authorization of the Loan Documents by, the Borrower) of the opinion, dated today, of the Vice President and General Counsel of the Borrower which is being delivered to you pursuant to Section 3.1(e) of the Credit Agreement. In rendering the opinions expressed in paragraph 2 above we have made no examination of any accounting or financial matters and express no opinion with respect thereto. We have not been called upon to, and accordingly do not, express any opinion as to the various state and Federal laws regulating banks or the conduct of their business (except Regulation U issued by the Federal Reserve Board) that may relate to the Loan Documents or the transactions contemplated thereby. Without limiting the generality of the foregoing, we express no opinion as to the effect of the law of any jurisdiction other than the State of Texas wherein any Bank may be located or where any enforcement of the Loan Documents may be sought which limits the rates of interest legally chargeable or collectible. This opinion is limited to the laws of the State of Texas, the General Corporation Law of the State of Delaware and the Federal law of the United States. The opinions herein have been furnished at your request and are solely for your benefit and the benefit of your respective successors, assigns, participants, and other transferees in connection with the subject transaction and may not be relied upon by any other person or by you or any other person in any other context without the prior written consent of the undersigned. Very truly yours, Vinson & Elkins L.L.P. EXHIBIT D Enron Oil & Gas Company {Date} To each of the Banks parties to the Revolving Credit Agreement dated as of March 11, 1994 among Enron Oil & Gas Company, said Banks and Texas Commerce Bank National Association as Administrative Agent for said Banks and to such Administrative Agent Re: $100,000,000 Revolving Credit Agreement of even date herewith among Enron Oil & Gas Company, as Borrower, the Banks named therein and Texas Commerce Bank National Association, as Administrative Agent Ladies and Gentlemen: As Vice President and General Counsel of Enron Oil & Gas Company, a Delaware corporation (the "Borrower"), I am familiar with the Revolving Credit Agreement (the "Credit Agreement") dated as of March 11, 1994 among the Borrower, the Banks listed on the signature pages thereto and Texas Commerce Bank National Association as Administrative Agent for said Banks. In such capacities, I am also familiar with the Restated Certificate of Incorporation, as amended, and By-laws, as amended, of the Borrower. This opinion is being furnished to you pursuant to Section 3.1(e) of the Credit Agreement. Terms defined in the Credit Agreement and not otherwise defined are used herein as therein defined. Before rendering the opinion hereinafter set forth, I (or other attorneys with the Borrower's legal department acting under my direction) have examined the Loan Documents, and have examined and relied upon originals or photostatic or certified copies of such corporate records, certificates of officers of the Borrower and of public officials, and such agreements, documents and instruments, and made such investigations of law, as I or such other attorneys have deemed relevant and necessary as the basis for the opinion hereinafter expressed. In such examination, I or such other attorneys assumed the genuineness of all signatures (other than signatures of officers of the Borrower on the Loan Documents) and the authenticity of all documents submitted to us as originals, and the conformity to original documents of all documents submitted to us as photostatic or certified copies. Upon the basis of the foregoing, I am of the opinion that: 1. The Borrower is a corporation duly organized, validly existing and in good standing under the laws of the State of Delaware, and has all corporate powers and all governmental licenses, authorizations, consents and approvals required to carry on its business as now conducted, except to the extent failure to obtain such licenses, authorizations, consents or approvals would not materially adversely affect the Borrower and its Subsidiaries taken as a whole. 2. The execution, delivery and performance by the Borrower of each Loan Document are within the Borrower's corporate powers, have been duly authorized by all necessary corporate action on the part of the Borrower, and do not contravene, or constitute a default under, (a) the Restated Certificate of Incorporation, as amended, or By-laws, as amended, of the Borrower, (b) any contractual restriction contained in any material (meaning for the purposes of this opinion those creating a monetary liability of $50,000,000 or more) indenture, loan or credit agreement, receivables sale or financing agreement, lease financing agreement, capital lease, mortgage, security agreement, bond or note, or any guaranty of any of such obligations to which the Borrower is a party, or (c) any judgment, injunction, order or decree known to me binding upon the Borrower. The execution, delivery and performance by the Borrower of each of the Loan Documents will not result in the creation or imposition of any lien, security interest or other charge or encumbrance on any asset of the Borrower or any Subsidiary. The Credit Agreement and the Notes have been duly executed and delivered by the Borrower. 3. Except as disclosed in the Borrower's Form 10-K for the year ended December 31, 1992, or the Borrower's Form 10-Q for each of the quarters ended March 31, 1993, June 30, 1993 and September 30, 1993, there is no action, suit or proceeding pending or, to my knowledge, threatened against the Borrower before any court or arbitrator or any governmental agency, in which there is a reasonable possibility of an adverse decision which could materially adversely affect the consolidated financial position or consolidated results of operations of the Borrower and its Subsidiaries taken as a whole or which in any manner draws into question the validity of the Credit Agreement or any other Loan Document. 4. Neither the Borrower nor any Subsidiary is an "investment company" within the meaning of the Investment Company Act of 1940, as amended. 5. Neither the Borrower nor any Principal Subsidiary is a "holding company", a "subsidiary company" of a "holding company", an "affiliate" of a "holding company", or an "affiliate" of a "subsidiary company" of a "holding company", in each case as such terms are defined in the Public Utility Holding Company Act of 1935, as amended, or regulated pursuant to such Act or the rules and regulations promulgated thereunder or any order or interpretation of the Securities and Exchange Commission or its staff issued pursuant thereto. The opinions set forth above are subject to the following qualifications: 1. In rendering the opinions expressed in paragraph 2 above, neither I nor any other attorney acting under my direction have made any examination of any accounting or financial matters related to certain of the covenants contained in certain documents to which the Borrower may be subject, and I express no opinion with respect thereto. 2. This opinion is limited in all respects to the laws of the State of Texas and the General Corporation Law of the State of Delaware and the Federal law of the United States. 3. In rendering the opinion expressed in paragraph 3 above, I (or the other attorneys acting under my direction) have only reviewed the files and records of the Borrower and the Subsidiaries, and we have consulted with such senior officers of the Borrower and the Subsidiaries as we have deemed necessary. This opinion is solely for the benefit of the Banks, the Administrative Agent, and their respective successors, assigns, participants and other transferees, and may not be relied upon in connection with any other transaction or by any other person; provided, however, that Vinson & Elkins L.L.P. may rely on certain provisions of this opinion to the extent stated in its opinion for the purposes of rendering its opinion pursuant to Section 3.1(d) of the Credit Agreement. Very truly yours, Dennis M. Ulak EXHIBIT E NOTICE OF CONVERSION Texas Commerce Bank National Association, as Administrative Agent 712 Main Street Houston, Texas 77002 {Date} Attention: Manager, Energy Group 5 TCB-N 86 Ladies and Gentlemen: The undersigned, Enron Oil & Gas Company, refers to the Revolving Credit Agreement, dated as of March 11, 1994 (such Revolving Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT", the terms defined therein being used herein as therein defined), among the undersigned, certain Banks parties thereto and Texas Commerce Bank National Association, as Administrative Agent for said Banks, and hereby gives you notice, irrevocably, pursuant to SECTION 2.8 of the Credit Agreement that the undersigned hereby requests a Conversion under the Credit Agreement, and in that connection sets forth below the information relating to such Conversion (the "PROPOSED CONVERSION") as required by SECTION 2.8 of the Credit Agreement: (1) The Business Day of the Proposed Conversion is , 199___. (2) The Advances to be converted are: (3) The Advances are to be Converted into the following Types and amounts of Advances: {Base Rate Advances} {Adjusted CD Rate Advances} {Eurodollar Advances}: {(4) The initial Interest Period for each such Advance is (days) (months).} Very truly yours, ENRON OIL & GAS COMPANY By: Title: EXHIBIT F Section 1007. NEGATIVE PLEDGE AND EXCEPTIONS THERETO. Except as otherwise specified as contemplated by Section 301 for Securities of any series, so long as any of the Securities are outstanding, the Company will not create or suffer to exist, or permit any of its Subsidiaries to create or suffer to exist, except in favor of the Company or any Subsidiary, any Lien upon any Principal Property at any time owned by it, to secure any Funded Debt of the Company or any Subsidiary, without making effective provisions whereby the Securities shall be equally and ratably secured with any and all such Funded Debt and with any other indebtedness similarly entitled to be equally and ratably secured; provided, however, that this restriction shall not apply to or prevent the creation or existence of any: (a) Acquisition Lien or Permitted Encumbrance; or (b) Lien created or assumed by the Company or any Subsidiary in connection with the issuance of debt securities the interest on which is excludable from gross income of the holder of such security pursuant to the Internal Revenue Code of 1986, as amended, for the purpose of financing, in whole or in part, the acquisition or construction of property or assets to be used by the Company or a Subsidiary. In case the Company or any Subsidiary shall propose to create or permit to exist a Lien on any Principal Property at any time owned by it to secure any Funded Debt of the Company or any Subsidiary, other than Funded Debt permitted to be secured under clauses (a) or (b) of this Section 1007, the Company will prior thereto give written notice thereof to the Trustee, and the Company will, or will cause such Subsidiary to, prior to or simultaneously with such creation or permission to exist, by supplemental indenture executed to the Trustee (or to the extent legally necessary to another trustee or additional or separate trustee), in form satisfactory to the Trustee, effectively secure all the Securities equally and ratably with such Funded Debt and any other indebtedness entitled to be equally and ratably secured. Notwithstanding the foregoing provisions of this Section 1007, the Company or a Subsidiary may issue, assume or guarantee Funded Debt secured by Liens which would otherwise be subject to the foregoing restrictions in an aggregate amount which, together with all other Funded Debt of the Company or a Subsidiary secured by Liens which (if originally issued, assumed or guaranteed at such time) would otherwise be subject to the foregoing restrictions (not including Funded Debt permitted to be secured under clauses (a) or (b) above) does not at the time exceed 10% of the Consolidated Net Tangible Assets of the Company, as shown on the audited consolidated financial statements of the Company as of the end of the fiscal year preceding the date of determination. "Acquisition Lien" means any (i) Lien upon any property heretofore or hereafter acquired, created at the time of acquisition or within one year thereafter to secure all or a portion of the purchase price thereof, or existing thereon at the date of acquisition, whether or not assumed by the Company or any Subsidiary, provided that any such Lien shall apply only to the property so acquired and fixed improvements thereon, (ii) Lien upon any property heretofore or hereafter acquired by any corporation that is or becomes a Subsidiary after the date hereof ("Acquired Entity"), provided that any such Lien (1) shall either (A) exist prior to the time the Acquired Entity becomes a Subsidiary or (B) be created at the time the Acquired Entity becomes a Subsidiary or within one year thereafter to secure all or a portion of the acquisition price thereof and (2) shall only apply to those properties owned by the Acquired Entity at the time it becomes a Subsidiary or thereafter acquired by it from sources other than the Company or any other Subsidiary, and (iii) any extension, renewal or refunding, in whole or in part, of any Lien permitted by clause (i) or (ii) above, if limited to the same property or any portion thereof subject to, and securing not more than the amount secured by, the Lien extended, renewed or refunded. "Consolidated Net Tangible Assets" means total assets less (a) total current liabilities (excluding indebtedness due within 12 months) and (b) goodwill, patents and trademarks, all as reflected in the Company's audited consolidated balance sheet preceding the date of a determination under the last paragraph of Section 1007. "Funded Debt" as applied to the Company or any Subsidiary means all indebtedness incurred, created, assumed or guaranteed by the Company or any Subsidiary, or upon which such corporation customarily pays interest charges, which matures, or is renewable by the Company or any Subsidiary to a date, more than one year after the date as of which Funded Debt is being determined. "indebtedness", as applied to the Company or any Subsidiary, shall mean bonds, debentures, notes and other instruments representing obligations created or assumed by any such corporation for the repayment of money borrowed (other than unamortized debt discount or premium). All indebtedness secured by a Lien upon property owned by the Company or any Subsidiary and upon which indebtedness any such corporation customarily pays interest, although any such corporation has not assumed or become liable for the payment of such indebtedness, shall for all purposes hereof be deemed to be indebtedness of any such corporation. All indebtedness for money borrowed incurred by other persons which is directly guaranteed as to payment of principal by the Company or any Subsidiary shall for all purposes hereof be deemed to be indebtedness of any such corporation, but no other contingent obligation of any such corporation in respect of indebtedness incurred by other persons shall for any purpose be deemed indebtedness of such corporation. Indebtedness of the Company or any Subsidiary shall not include (i) any amount representing capitalized lease obligations; (ii) indirect guarantees or other contingent obligations in connection with the indebtedness of others, including agreements, contingent or otherwise, with such other persons or with third persons with respect to, or to permit or ensure the payment of, obligations of such other persons, including, without limitation, agreements to purchase or repurchase obligations of such other persons, agreements to advance or supply funds to or to invest in such other persons or agreements to pay for property, products, or services of such other persons (whether or not conferred, delivered or rendered), and any demand charge, throughput, take-or-pay, keep-well, make-whole, cash deficiency, maintenance of working capital or earnings or similar agreements; and (iii) any guarantees with respect to lease or other similar periodic payments to be made by other persons. "Lien" means any mortgage, pledge, lien, security interest or similar charge or encumbrance. "Permitted Encumbrances" means any (a) undetermined or inchoate Lien incidental to construction, maintenance, development or operation of any property; (b) Lien for any tax or assessment for the then current year; (c) Lien for any tax or assessment not at the time delinquent; (d) Lien for specified tax or assessment which is delinquent but the validity of which is being contested at the time by the Company or any Subsidiary in good faith; (e) Lien reserved in any oil, gas or other mineral lease for rent, royalty or delay rental under such lease and for compliance with the terms of such lease; (f) Lien for any judgments or attachments in an aggregate amount not in excess of $10,000,000, or for any judgment or attachment the execution or enforcement of which has been stayed or which has been appealed and secured, if necessary, by the filing of appeal bond; (g) mechanics' or materialmen's Lien, any Lien or charge arising by reason of any pledge or deposit to secure payment of workmen's compensation or other insurance, good faith deposit in connection with any tender, lease of real estate, bid or contract (other than any contract for the payment of indebtedness), deposit to secure any duty or public or statutory obligation, deposit to secure, or in lieu of, surety, stay or appeal bond, and deposit as security for the payment of any tax or assessment or similar charge; (h) Lien arising by reason of any deposit with, or the giving of any form of security to, any governmental agency or any body created or approved by law for any purpose at any time in connection with the financing of the acquisition or construction of property to be used in the business of the Company or Subsidiary or as required by law as a condition to the transaction of any business or the exercise of any privilege or license, or to enable the Company or a Subsidiary to maintain self-insurance or to participate in any fund established to cover any insurance risk or in connection with workmen's compensation, unemployment insurance, old age pension or other social security, or to share in the privileges or benefits required for companies participating in such arrangements; (i) easement, servitude, right-of-way or other right, exception, reservation, condition, limitation, covenant or other restriction or imperfection in title which does not materially detract from or interfere with the operation, value or use of the properties affected thereby; (j) preferential right to purchase entered into the ordinary course of business; (k) conventional provision contained in any contract or agreement affecting properties under which the Company or a Subsidiary is required immediately before the expiration, termination or abandonment of a particular property to reassign to the Company's or a Subsidiary's predecessor in title all or a portion of the Company's or a Subsidiary's rights, titles and interest in and to all or a portion of such property; (l) sale or other transfer of crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances in place, or the future production thereof, for a period of time until, or in an amount such that, the transferee will realize therefrom a specified amount (however determined) of money or a specified amount of such crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances or any sale or other transfer of any other interest in property of the character commonly referred to as a "production payment," "overriding royalty," "net profits interest," "royalty" or similar burden on any oil and gas property or mineral interest owned by the Company or any Subsidiary; (m) Lien consisting of or reserved in any (i) grant or conveyance in the nature of a farm-out or conditional assignment to the Company or any of its Subsidiaries entered into the ordinary course of business to secure undertakings of the Company or any Subsidiary in such grant or conveyance, (ii) interest of an assignee of any proved undeveloped lease or proved undeveloped portion of any producing property transferred to such assignee for the purpose of the development of such lease or property, (iii) unitization or pooling agreement or declaration, (v) contract for the sale, purchase, exchange or processing of production, or (v) operating agreement, area of mutual interest agreement or other agreement which is customary in the oil and gas business and which agreement does not materially detract from the value, or materially impair the use of, the property affected thereby; (n) Lien consisting of any (i) statutory landlord's lien under any lease to which the Company or any Subsidiary is a party or any other Lien on leased property reserved in any lease thereof for rent or for compliance with the terms of such lease, (ii) right reserved to or vested in any municipality or governmental, statutory or public authority to control or regulate any property of the Company or any Subsidiary or to use such property in any manner which does not materially impair the use of such property for the purpose for which it is held by the Company or any such Subsidiary, (iii) obligation or duty to any municipality or public authority with respect to any franchise, grant, license, lease or permit and the rights reserved or vested in any governmental authority or public utility to terminate any such franchise, grant, license, lease or permit or to condemn or expropriate any property, or (iv) zoning law, ordinance or municipal regulation; (o) Lien arising out of any forward contract, futures contract, swap agreement or other commodities contract entered into by the Company or any Subsidiary; (p) Lien on oil and gas property of the Company or any Subsidiary thereof, or on production therefrom, to secure any liability of the Company or such Subsidiary for all or part of the Development Cost for such property under any joint operating, drilling or similar agreement for exploration, drilling or development of such property, or any renewal or extension of any such Lien (as used in this subclause, "Development Cost" means, for any oil and gas property, the cost of exploration, drilling or development of such property or of altering or repairing equipment used in connection with such exploration, drilling or development, or in the case of property which is substantially unimproved for the use intended by the Company or such Subsidiary, the cost of construction of improvements directly related to such exploration, drilling or development of such property); (q) Lien on any property of the Company or any Subsidiary thereof in favor of the government of the United States of America or of any State, or any political subdivision of either thereof, or any department, agency or instrumentality of either thereof (collectively, "Governments"), in order to permit the Company or such Subsidiary to perform any contract or subcontract made with or at the request of such Government, securing any partial, progress, advance or other payment by such Government to the Company or such Subsidiary under such contract or subcontract, to the extent such Lien is required by such contract or subcontract or by any law relating thereto; and (r) Lien to secure any indebtedness incurred in connection with the construction, installation or financing of any pollution control or abatement facility or other form of industrial revenue bond financing issued or guaranteed by the United States, any State or any department, agency or instrumentality of either. "Principal Property" means any property interest in oil and gas reserves located in the United States or offshore the United States owned by the Company or any Subsidiary and which is capable of producing crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances in paying quantities, the net book value of which property interest or interests exceeds two (2) percent of Consolidated Net Tangible Assets, except any such property interest or interests that in the opinion of the Board of Directors is not of material importance to the total business conducted by the Company and its Subsidiaries as a whole. Without limitation, the term "Principal Property" shall not include (i) accounts receivable and other obligations of any obligor under a contract for the sale, exploration, production, drilling, development, processing or transportation of crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances by the Company or any of its Subsidiaries, and all related rights of the Company or any of is Subsidiaries, and all guarantees, insurance, letters of credit and other agreements or arrangements of whatever character supporting or securing payment of such receivables or obligations, or (ii) the production or any proceeds from production of crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances. "Subsidiary" means a corporation more than 50% of the outstanding voting stock of which is owned, directly or indirectly, by the Company or by one or more other Subsidiaries, or by the Company and one or more other Subsidiaries. For the purposes of this definition, "voting stock" means stock which ordinarily has voting power for the election of directors, whether at all times or only so long as no senior class of stock has such voting power by reason of any contingency. PROMISSORY NOTE U.S. $30,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of TEXAS COMMERCE BANK NATIONAL ASSOCIATION (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of THIRTY MILLION U.S. dollars (U.S. $30,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Anount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $20,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of THE BANK OF NEW YORK (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TWENTY MILLION U.S. dollars (U.S. $20,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $10,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of THE BANK OF NOVA SCOTIA (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TEN MILLION U.S. dollars (U.S. $10,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $10,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of CREDIT LYONNAIS CAYMAN ISLAND BRANCH (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TEN MILLION U.S. dollars (U.S. $10,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $10,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of CREDIT SUISSE (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TEN MILLION U.S. dollars (U.S. $10,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $10,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of THE FIRST NATIONAL BANK OF CHICAGO (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TEN MILLION U.S. dollars (U.S. $10,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
PROMISSORY NOTE U.S. $10,000,000.00 Houston, Texas March 11, 1994 FOR VALUE RECEIVED, the undersigned, Enron Oil & Gas Company, a Delaware corporation (the "BORROWER"), HEREBY PROMISES TO PAY to the order of BANK OF AMERICA NATIONAL TRUST AND SAVINGS ASSOCIATION (the "BANK") for the account of its Applicable Lending Office (as defined in the Credit Agreement referred to below) on or before January 15, 1998 the principal sum of TEN MILLION U.S. dollars (U.S. $10,000,000.00) or, if less, the aggregate unpaid principal amount of the Advances (as defined in the Revolving Credit Agreement of even date herewith among the Borrower, the Bank, certain other lenders parties thereto and Texas Commerce Bank National Association, as Administrative Agent for the Bank and such other lenders; such Credit Agreement, as amended from time to time being herein referred to as the "CREDIT AGREEMENT") owing to the Bank outstanding on the Termination Date; PROVIDED that for the full term of this Promissory Note the interest rate produced by the aggregate of all sums paid or agreed to be paid to the holder of this Promissory Note for the use, forbearance or detention of the debt evidenced hereby shall not exceed the Highest Lawful Rate (as defined in the Credit Agreement). The Borrower promises to pay interest on the unpaid principal amount of each Advance owing to the Bank from the date of such Advance until such principal amount is paid in full, at such interest rates, and due at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to Texas Commerce Bank National Association, as Administrative Agent, at 712 Main Street, Houston, Texas, in same day funds. Each Advance owed to the Bank by the Borrower pursuant to the Credit Agreement, and all payments made on account of principal thereof, shall be recorded by the Bank and, prior to any transfer hereof, endorsed on the grid attached hereto which is part of this Promissory Note; PROVIDED that the failure of the Bank to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is subject to and is entitled to the benefits of, the Credit Agreement. The Credit Agreement, among other things, (a) provides for the making of Advances by the Bank to the Borrower from time to time in an aggregate amount not to exceed at any one time outstanding the U.S. dollar amount first above mentioned, the indebtedness of the Borrower resulting from each Advance owing to the Bank being evidenced by this Promissory Note, and (b) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. Unless otherwise defined herein, any term used in this Promissory Note and defined in the Credit Agreement shall have the meaning ascribed to it in the Credit Agreement. Except only for any notices which are specifically required by the Credit Agreement, the Borrower waives notice (including, but not limited to, notice of intent to accelerate and notice of acceleration, notice of protest and notice of dishonor), demand, presentment for payment and protest. THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF TEXAS. ENRON OIL & GAS COMPANY, a Delaware corporation By: W. C. Wilson Title: Sr. Vice President and Chief Financial Officer ADVANCES AND PAYMENTS OF PRINCIPAL
Amount of Amount Principal Unpaid of Type of Paid or Principal Notation Date Advance Advance Prepaid Balance Made By
EX-10.16 5 INTEREST RATE AND CURRENCY EXHANGE AGREEMENT EXHIBIT 10.16 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Manager, Marketing Administration From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: March 25, 1991 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement: Dated As Of: January 1, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOGM") And: Enron Finance Corp. ("EFC") All provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). Page 2 Quantity Per Period: QUANTITY PER DAY PERIOD PER PERIOD (a) April 1991 20,000 MMBtu (b) May 1991 40,000 MMBtu (c) June 1991 through December 1991 60,000 MMBtu (d) January 1992 through December 2000 40,000 MMBtu "MMBtu" means one million British thermal units. Effective Date: April 1, 1991 Termination Date: December 31, 2000 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EFC Payment Dates: Three Business Days after each Period Date. Period End Dates: The last day of each calendar month with the first Period End Date being April 30, 1991. Fixed Amount: $_____ ($2.45 per MMBtu x Quantity Per Day Per Period x the number of Days in the Period. Period: Each Calendar month beginning with April 1991. The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EOGM Payment Dates: Twenty-five Business days after each Period End Date. Period End Dates: The last day of each calendar month with the first period Page 3 End Date being April 30, 1991. Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with April 1991. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following Day which is a New York Banking Day. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds to us, please pay: Citibank, New York, NY; ABA Routing Number 021000089 For the Account of: Enron Corp. for the benefit of Enron Finance Corp. Account Number: 00076486 We will pay you: Through the Fedwire to First City National Bank, Houston, Texas, ABA Routing No. 113000010, for credit to Enron Oil & Gas Marketing, Inc. Account No. 001-00-8640. Each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/750-6831) within three New York Banking Days following receipt of this Page 4 Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON FINANCE CORP. By: Name: Mark E. Haedicke Title: Vice President and General Counsel ENRON OIL & GAS MARKETING, INC. By: Name: G. E. Uthlaut Title: Senior Vice President, Operations To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Manager, Marketing Administration From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: April 25, 1991 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement: Dated As Of: March 25, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOGM") And: Enron Finance Corp. ("EFC") All provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. Page 2 The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). Quantity Per Period: QUANTITY PER DAY PERIOD PER PERIOD (a) April 1991 20,000 MMBtu (b) May 1991 40,000 MMBtu (c) June 1991 through December 1991 60,000 MMBtu (d) January 1992 through December 2000 40,000 MMBtu "MMBtu" means one million British thermal units. Effective Date: April 1, 1991 Termination Date: December 31, 2000 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EFC Payment Dates: On or before the twenty-fifth (25th) day of the calendar month after each Period End Date. Period End Dates: The last day of each calendar month with the first Period End Date being April 30, 1991. Fixed Amount: $_____ ($2.45 per MMBtu x Quantity Per Day Per Period x the number of Days in the Period. Period: Each Calendar month beginning with April 1991. Page 3 The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EOGM Payment Dates: On or before the twenty-fifth (25th) day of the calendar month after each Period End Date. Period End Dates: The last day of each calendar month with the first period End Date being April 30, 1991. Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with April 1991. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds to us, please pay: Hibernia National of New Orleans; ABA Routing Number 065000090 For the Account of: Enron Finance Corp. Account Number: 812141872 We will pay you: Through the Fedwire to NCNB, Houston, Texas, ABA Routing No. 111000025, for credit to Enron Oil & Gas Marketing, Inc. Account No. 414-032-9304. Page 4 Subject to the netting of cross payments as provided in the master swap agreement, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/750-6831) within three New York Banking Days following receipt of this Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON FINANCE CORP. By: Name: John J. Esslinger Title: President ENRON OIL & GAS MARKETING, INC. By: Name: Andrew N. Hoyle Title: Vice President, Marketing To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Business Development Dept. From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: September 23, 1992 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: March 25, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOG") And: Enron Finance Corp. ("EFC") Upon execution, all provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. Page 2 The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). Quantity Per Period: QUANTITY PER DAY PERIOD PER PERIOD October 1, 1992 thru 40,000 MMBtu December 31, 1995 "MMBtu" means one million British thermal units. Effective Date: October 1, 1992 Termination Date: December 31, 1995 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Dates: The last day of each calendar month with the first Period End Date being October 31, 1992. Fixed Amount: $2.45/MMBtu/Dry x 40,000 MMBtu per day for October, 1992 through December, 1995. Period: Each Calendar month beginning with October, 1992. The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EFC Page 3 Payment Dates: Twenty-five Business days after each Period End Date. Period End Dates: The last day of each calendar month with the first period End Date being October 31, 1992. Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with October, 1992. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following Day which is a New York Banking Day. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds Nations Bank of Texas to us, please pay: ABA Routing Number 111000025 For the Account of: Enron Finance Corp. Account Number: 414 032 9339 We will pay you: Through the Fedwire to NCNB, Houston, Texas, ABA Routing No. 111000025, for credit to Enron Oil & Gas Marketing, Inc. Account No. 414-032-9304. Page 4 Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/646-3239) within three New York Banking Days following receipt of this Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING,INC. ENRON FINANCE CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President September 22, 1992 Date: 9/28/92 EX-10.17 6 ASSIGNMENTS AND ASSUMPTION AGREEMENTS EXHIBIT 10.17 ASSIGNMENT AND ASSUMPTION AGREEMENT THIS ASSIGNMENT AND ASSUMPTION AGREEMENT, dated as of November 1, 1993, is entered into by and between ENRON OIL & GAS MARKETING, INC. ("EOGM"), ENRON OIL & GAS COMPANY ("EOG") and ENRON RISK MANAGEMENT SERVICES CORP. ("ERMS"). RECITALS WHEREAS, EOGM and ERMS are parties to that certain Interest Rate and Currency Exchange Agreement dated as of June 1, 1991 (the "ERMS/EOGM Exchange Agreement"); and WHEREAS, EOGM and ERMS have entered into certain swap transactions (the "Swap Transactions") governed by and subject to the terms and conditions set forth in the ERMS/EOGM Exchange Agreement and in documents exchanged between EOGM and ERMS confirming the Swap Transactions (the "Confirmations"); and WHEREAS, EOGM desires to assign to EOG all its rights and obligations in and to certain Swap Transactions, and EOG desires to assume all such rights and obligations from EOGM; AGREEMENT NOW, THEREFORE, in consideration of the premises and of the mutual covenants and agreements herein contained, the parties hereto agree as follows: 1. ASSIGNMENT OF RIGHTS AND ASSUMPTION OF OBLIGATIONS. Effective as of November 1, 1993, EOGM hereby assigns to EOG all its rights and obligations under the ERMS/EOGM Exchange Agreement in connection with the Swap Transactions set forth in the Confirmations attached hereto as EXHIBIT A (the "Assigned Transactions"). EOG hereby accepts such assignment and assumes all obligations of EOGM under the ERMS/EOGM Exchange Agreement and the Confirmations related to the Assigned Transactions. 2. RESERVED TRANSACTIONS. The parties acknowledge and agree that the Swap Transactions set forth in the Confirmations attached hereto as EXHIBIT B (the "Reserved Transactions") shall not be included in this assignment to and assumption by EOG. The parties further agree that the Reserved Transactions shall continue, without interruption, to be governed by the ERMS/EOGM Exchange Agreement; and notwithstanding the assignment and assumption of the Assigned Transactions hereunder, the ERMS/EOGM Exchange Agreement shall remain in full force and effect with respect to such Reserved Transactions and any future swap transactions between ERMS and EOGM. 3. CONSENT OF ERMS. ERMS hereby consents to the assignment and assumption described herein and releases EOGM from all obligations under the ERMS/EOGM Exchange Agreement and the Confirmations with respect to the Assigned Transactions. 4. ERMS/EOG MASTER AGREEMENT. The parties acknowledge and understand that ERMS and EOG will enter into a Master Agreement (the "ERMS/EOG Master Agreement") dated as of even date herewith, which will govern (i) the Assigned Transactions and (ii) future Transactions (as defined in the ERMS/EOG Master Agreement) between ERMS and EOG. The parties agree that the Assigned Transactions shall be governed by the ERMS/EOG Master Agreement, and the ERMS/EOGM Exchange Agreement shall no longer be of force and effect with respect to the Assigned Transactions as of the date of the ERMS/EOG Master Agreement. 5. GOVERNING LAW. This Assignment and Assumption Agreement shall be subject to and construed, enforced and performed in accordance with the laws of the State of Texas. 6. COUNTERPARTS. This Assignment and Assumption Agreement may be executed by the parties hereto in separate counterparts, each of which when so executed and delivered shall be an original. All such counterparts shall be deemed, when taken together, to be but one and the same instrument. IN WITNESS WHEREOF, the parties hereto have duly executed this Assignment and Assumption Agreement on the day and year first written above. ENRON OIL & GAS MARKETING, INC. ENRON OIL & GAS COMPANY By By Name Andrew N. Hoyle Name George E. Uthlaut Title Vice President, Marketing Title Senior Vice President, Operations ENRON RISK MANAGEMENT SERVICES CORP. By Name Lou L. Pai Title President -2- EXHIBIT A ASSIGNED TRANSACTIONS 1. Confirmation #1268.0, dated February 10, 1993, with an Effective Date of March 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 2. Confirmation #1286.0, dated February 12, 1993, with an Effective Date of March 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 3. Confirmation #1291.0, dated February 16, 1993, with an Effective Date of January 1, 1994; Termination Date of February 28, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 4. Confirmation #1292.0, dated February 16, 1993, with an Effective Date of April 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 5. Confirmation #1304.0, dated February 17, 1993, with an Effective Date of April 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 6. Confirmation #1305.0, dated February 17, 1993, with an Effective Date of January 1, 1994; Termination Date of February 28, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 7. Confirmation #1321.0, dated February 19, 1993, with an Effective Date of January 1, 1994; Termination Date of February 28, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 8. Confirmation #1335.0, dated February 23, 1993, with an Effective Date of April 1, 1993; Termination Date of February 28, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 9. Confirmation #1338.0, dated February 25, 1993, with an Effective Date of December 1, 1993; Termination Date of February 28, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM A-1 10. Confirmation #1370.0, dated March 12, 1993, with an Effective Date of May 1, 1993; Termination Date of March 31, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 11. Confirmation #1471.0, dated April 6, 1993, with an Effective Date of December 1, 1993; Termination Date of January 31, 1994. Fixed Price Payor: EOGM Floating Price Payor: ERMS 12. Confirmation #1485.0, dated April 13, 1993, with an Effective Date of March 1, 1994; Termination Date of October 31, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 13. Confirmation #1486.0, dated April 13, 1993, with an Effective Date of June 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 14. Confirmation #1494.0, dated April 13, 1993, with an Effective Date of March 1, 1994; Termination Date of October 31, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 15. Confirmation #1495.0, dated April 13, 1993, with an Effective Date of June 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM 16. Confirmation #1509.0, dated April 13, 1993, with an Effective Date of August 1, 1994; Termination Date of September 30, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 17. Confirmation #1514.0, dated April 15, 1993, with an Effective Date of March 1, 1994; Termination Date of October 31, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 18. Confirmation #1533.01, dated April 26, 1993, with an Effective Date of August 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: ERMS Floating Price Payor: EOGM A-2 19. Confirmation #1569.0, dated April 25, 1993, with an Effective Date of March 1, 1994; Termination Date of October 31, 1994. Fixed Price Payor: ERMS Floating Price Payor: EOGM 20. Confirmation #1986.0, dated July 14, 1993, with an Effective Date of August 1, 1993; Termination Date of December 31, 1993. Fixed Price Payor: EOGM Floating Price Payor: ERMS 21. Confirmation #2217.0, dated August 23, 1993, with an Effective Date of December 1, 1993; Termination Date of February 28, 1994. Fixed Price Payor: EOGM Floating Price Payor: ERMS 22. Confirmation #2227.0, dated August 25, 1993, with an Effective Date of February 1, 1994; Termination Date of February 28, 1994. Fixed Price Payor: EOGM Floating Price Payor: ERMS 23. Confirmation #2278.0, dated September 7, 1993, with an Effective Date of October 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: EOGM Floating Price Payor: ERMS 24. Confirmation #2299.0, dated September 10, 1993, with an Effective Date of October 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: EOGM Floating Price Payor: ERMS 25. Confirmation #2372.0, dated September 16, 1993, with an Effective Date of October 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: EOGM Floating Price Payor: ERMS 26. Confirmation #2647.0, dated October 6, 1993, with an Effective Date of November 1, 1993; Termination Date of November 30, 1993. Fixed Price Payor: EOGM Floating Price Payor: ERMS A-3 EXHIBIT B RESERVED TRANSACTIONS 1. Confirmation #0000644, dated June 14, 1992, with an Effective Date of January 1, 1996; Termination Date of December 31, 2000. Fixed Price Payor: EOGM Floating Price Payor: ERMS 2. Confirmation dated March 25, 1991, with an Effective Date of April 1, 1991; Termination Date of December 31, 2000. Fixed Price Payor: ERMS (successor-in-interest of EFC) Floating Price Payor: EOGM 3. Confirmation dated April 25, 1991, with an Effective Date of April 1, 1991; Termination Date of December 31, 2000. Fixed Price Payor: ERMS (successor-in-interest of EFC) Floating Price Payor: EOGM 4. Confirmation Letter dated September 23, 1992, with an Effective Date of October 1, 1992; Termination Date of December 31, 1995. Fixed Price Payor: EOGM Floating Price Payor: ERMS (successor-in-interest of EFC) NOTE: Items 2-4, originally issued pursuant to that certain Interest Rate and Currency Exchange Agreement between Enron Finance Corp. ("EFC") and EOGM dated as of March 25, 1991, has been assigned to and assumed by ERMS pursuant to that certain Assignment and Assumption Agreement between EFC, ERMS and EOGM dated as of even date herewith. Items 2-4 are now governed by the ERMS/EOGM Exchange Agreement. B-1 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 10, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1268.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1268.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD March 1, 1993 thru 120,000/MMBtu March 31, 1993 April 1, 1993 thru 510,000/MMBtu April 30, 1993 May 1, 1993 thru 580,000/MMBtu May 31,1993 June 1, 1993 thru 750,000/MMBtu June 30, 1993 July 1, 1993 thru 0/MMBtu July 31, 1993 August 1, 1993 thru 750,000/MMBtu August 31, 1993 September 1, 1993 thru 530,000/MMBtu September 30, 1993 October 1, 1993 thru 750,000/MMBtu October 31, 1993 November 1, 1993 thru 750,000/MMBtu November 30, 1993 December 1, 1993 thru 750,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1993 Termination Date: December 31, 1993 Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1268.0 Page 3 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Fixed Amount: $1.715/MMBtu/Dry x 120,000 MMBtu per day for the delivery month of March, 1993. $1.712/MMBtu/Dry x 510,000 MMBtu per day for the delivery month of April, 1993. $1.71/MMBtu/Dry x 580,000 MMBtu per day for the delivery month of May, 1993. $1.71/MMBtu/Dry x 750,000 MMBtu per day for the delivery month of June, 1993. $0.00/MMBtu/Dry x 0 MMBtu per day for the delivery month of July, 1993. $1.755/MMBtu/Dry x 750,000 MMBtu per day for the delivery month of August, 1993. $1.785/MMBtu/Dry x 530,000 MMBtu per day for the delivery month of September, 1993. $1.915/MMBtu/Dry x 750,000 MMBtu per day for the delivery month of October, 1993. $2.075/MMBtu/Dry x 750,000 MMBtu per day for the delivery month of November, 1993. $2.25/MMBtu/Dry x 750,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with March, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1268.0 Page 4 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1268.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 12, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 12, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1286.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD March 1, 1993 thru 30,000/MMBtu March 31, 1993 April 1, 1993 thru 30,000/MMBtu April 30, 1993 May 1, 1993 thru 30,000/MMBtu May 31,1993 June 1, 1993 thru 30,000/MMBtu June 30, 1993 July 1, 1993 thru 30,000/MMBtu July 31, 1993 August 1, 1993 thru 30,000/MMBtu August 31, 1993 September 1, 1993 thru 30,000/MMBtu September 30, 1993 October 1, 1993 thru 30,000/MMBtu October 31, 1993 November 1, 1993 thru 30,000/MMBtu November 30, 1993 December 1, 1993 thru 30,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1993 Termination Date: December 31, 1993 Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 3 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Fixed Amount: $1.72/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of March, 1993. $1.715/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of April, 1993. $1.697/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of May, 1993. $1.712/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of June, 1993. $1.715/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of July, 1993. $1.743/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of August, 1993. $1.775/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of September, 1993. $1.926/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of October, 1993. $2.084/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of November, 1993. $2.278/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with March, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 12, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 16, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1291.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD January 1, 1994 thru 60,000/MMBtu January 31, 1994 February 1, 1994 thru 60,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.276/MMBtu/Dry x 60,000 MMBtu per day for the delivery month of January, 1994. $1.988/MMBtu/Dry x 60,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 3 Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 16, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1292.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD April 1, 1993 thru 45,000/MMBtu April 30, 1993 May 1, 1993 thru 45,000/MMBtu May 31,1993 June 1, 1993 thru 45,000/MMBtu June 30, 1993 July 1, 1993 thru 45,000/MMBtu July 31, 1993 August 1, 1993 thru 45,000/MMBtu August 31, 1993 September 1, 1993 thru 45,000/MMBtu September 30, 1993 October 1, 1993 thru 45,000/MMBtu October 31, 1993 November 1, 1993 thru 45,000/MMBtu November 30, 1993 December 1, 1993 thru 45,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 3 Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Fixed Amount: $1.739/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of April, 1993. $1.72/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of May, 1993. $1.719/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of June, 1993. $1.719/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of July, 1993. $1.738/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of August, 1993. $1.763/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of September, 1993. $1.918/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of October, 1993. $2.076/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of November, 1993. $2.274/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 17, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1304.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD April 1, 1993 thru 25,000/MMBtu April 30, 1993 May 1, 1993 thru 25,000/MMBtu May 31,1993 June 1, 1993 thru 25,000/MMBtu June 30, 1993 July 1, 1993 thru 25,000/MMBtu July 31, 1993 August 1, 1993 thru 25,000/MMBtu August 31, 1993 September 1, 1993 thru 25,000/MMBtu September 30, 1993 October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 December 1, 1993 thru 25,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: December 31, 1993 Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 3 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Fixed Amount: $1.76/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of April, 1993. $1.742/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of May, 1993. $1.734/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of June, 1993. $1.736/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of July, 1993. $1.744/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of August, 1993. $1.77/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of September, 1993. $1.926/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.075/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. $2.266/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 17, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1305.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD January 1, 1994 thru 55,000/MMBtu January 31, 1994 February 1, 1994 thru 55,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.282/MMBtu/Dry x 55,000 MMBtu per day for the delivery month of January, 1994. $1.993/MMBtu/Dry x 55,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 3 Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with January, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 19, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1321.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD January 1, 1994 thru 10,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.265/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of January, 1994. $1.99/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 19, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 23, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1335.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD April 1, 1993 thru 25,000/MMBtu April 30, 1993 May 1, 1993 thru 25,000/MMBtu May 31,1993 June 1, 1993 thru 25,000/MMBtu June 30, 1993 July 1, 1993 thru 25,000/MMBtu July 31, 1993 August 1, 1993 thru 25,000/MMBtu August 31, 1993 September 1, 1993 thru 25,000/MMBtu September 30, 1993 October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 December 1, 1993 thru 20,000/MMBtu December 31, 1993 January 1, 1994 thru 20,000/MMBtu January 31, 1994 February 1, 1994 thru 15,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: February 28, 1994 Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 3 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Fixed Amount: $1.856/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of April, 1993. $1.794/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of May, 1993. $1.755/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of June, 1993. $1.745/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of July, 1993. $1.75/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of August, 1993. $1.77/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of September, 1993. $1.915/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.083/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. $2.26/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of December, 1993. $2.26/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of January, 1994. $1.985/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with April, 1993. Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 4 The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 23, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1338.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1338.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD December 1, 1993 thru 5,000/MMBtu December 31, 1993 January 1, 1994 thru 5,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Fixed Amount: $2.24/MMBtu/Dry x 5,000 MMBtu per day for the delivery month of December, 1993. $2.24/MMBtu/Dry x 5,000 MMBtu per day for the delivery month of January, 1994. $1.975/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with December, 1993. Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1338.0 Page 3 The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with January, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1338.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: March 12, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1370.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD May 1, 1993 thru 15,000/MMBtu May 31,1993 June 1, 1993 thru 15,000/MMBtu June 30, 1993 July 1, 1993 thru 15,000/MMBtu July 31, 1993 August 1, 1993 thru 15,000/MMBtu August 31, 1993 September 1, 1993 thru 15,000/MMBtu September 30, 1993 October 1, 1993 thru 15,000/MMBtu October 31, 1993 November 1, 1993 thru 15,000/MMBtu November 30, 1993 December 1, 1993 thru 10,000/MMBtu December 31, 1993 January 1, 1994 thru 10,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 March 1, 1994 15,000/MMBtu thru March 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: May 1, 1993 Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 3 Termination Date: March 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being April 23, 1993. Fixed Amount: $1.895/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of May, 1993. $1.842/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of June, 1993. $1.82/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of July, 1993. $1.815/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of August, 1993. $1.82/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of September, 1993. $1.92/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of October, 1993. $2.07/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of November, 1993. $2.235/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of December, 1993. $2.235/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of January, 1994. $1.985/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. $1.815/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of March, 1994. Period: Each calendar month beginning with May, 1993. Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 4 The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being April 23, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with May, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with May, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President March 12, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 6, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1471.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD December 1, 1993 thru 7,500/MMBtu December 31, 1993 January 1, 1994 thru 20,000/MMBtu January 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: January 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 22, 1993. Fixed Amount: $2.41/MMBtu/Dry x 7,500 MMBtu per day for the delivery month of December, 1993. $2.375/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of January, 1994. Period: Each calendar month beginning with December, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with December, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 4 Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President April 6, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1485.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD March 1, 1994 thru 155,000/MMBtu March 31, 1994 April 1, 1994 thru 150,000/MMBtu April 30, 1994 May 1, 1994 thru 155,000/MMBtu May 31, 1994 June 1, 1994 thru 150,000/MMBtu June 30, 1994 July 1, 1994 thru 155,000/MMBtu July 31, 1994 August 1, 1994 thru 155,000/MMBtu August 31, 1994 September 1, 1994 thru 150,000/MMBtu September 30, 1994 October 1, 1994 thru 155,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Fixed Amount: $2.091/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of March, 1994. $2.066/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of April, 1994. $2.076/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of May, 1994. $2.086/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of June, 1994. $2.096/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of July, 1994. $2.101/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of August, 1994. $2.108/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of September, 1994. $2.176/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1486.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD June 1, 1993 thru 10,000/MMBtu June 30, 1993 July 1, 1993 thru 10,000/MMBtu July 31, 1993 August 1, 1993 thru 10,000/MMBtu August 31, 1993 September 1, 1993 thru 10,000/MMBtu September 30, 1993 October 1, 1993 thru 10,000/MMBtu October 31, 1993 November 1, 1993 thru 10,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: June 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 3 Fixed Amount: $2.259/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of June, 1993. $2.233/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of July, 1993. $2.243/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of August, 1993. $2.252/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of September, 1993. $2.31/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of October, 1993. $2.422/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 4 Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1494.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD March 1, 1994 thru 620,000/MMBtu March 31, 1994 April 1, 1994 thru 600,000/MMBtu April 30, 1994 May 1, 1994 thru 620,000/MMBtu May 31, 1994 June 1, 1994 thru 600,000/MMBtu June 30, 1994 July 1, 1994 thru 620,000/MMBtu July 31, 1994 August 1, 1994 thru 620,000/MMBtu August 31, 1994 September 1, 1994 thru 600,000/MMBtu September 30, 1994 October 1, 1994 thru 620,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 3 Fixed Amount: $2.125/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of March, 1994. $2.085/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of April, 1994. $2.095/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of May, 1994. $2.11/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of June, 1994. $2.11/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of July, 1994. $2.11/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of August, 1994. $2.12/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of September, 1994. $2.20/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 4 Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1495.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD June 1, 1993 thru 10,000/MMBtu June 30, 1993 July 1, 1993 thru 10,000/MMBtu July 31, 1993 August 1, 1993 thru 10,000/MMBtu August 31, 1993 September 1, 1993 thru 10,000/MMBtu September 30, 1993 October 1, 1993 thru 10,000/MMBtu October 31, 1993 November 1, 1993 thru 10,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: June 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 3 Fixed Amount: $2.35/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of June, 1993. $2.33/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of July, 1993. $2.33/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of August, 1993. $2.35/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of September, 1993. $2.38/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of October, 1993. $2.49/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with June, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with June, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with June, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 4 Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1509.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD August 1, 1994 thru 15,000/MMBtu August 31, 1994 September 1, 1994 thru 15,000/MMBtu September 30, 1994 "MMBtu" means one million British thermal Units. August 1, 1994 Effective Date: Termination Date: September 30, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 22, 1994 Fixed Amount: $2.235/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of August, 1994. $2.23/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of September, 1994. Period: Each calendar month beginning with August, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 22, 1994. Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with June, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with August, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 4 Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President April 14, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 15, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1514.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD March 1, 1994 thru 15,000/MMBtu March 31, 1994 April 1, 1994 thru 15,000/MMBtu April 30, 1994 May 1, 1994 thru 15,000/MMBtu May 31, 1994 June 1, 1994 thru 15,000/MMBtu June 30, 1994 July 1, 1994 thru 15,000/MMBtu July 31, 1994 October 1, 1994 thru 15,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 3 Fixed Amount: $2.245/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of March, 1994. $2.21/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of April, 1994. $2.223/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of May, 1994. $2.235/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of June, 1994. $2.245/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of July, 1994. $2.315/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 4 Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC . ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 15, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 26, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1533.01 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD August 1, 1993 thru 50,000/MMBtu August 31, 1993 September 1, 1993 thru 50,000/MMBtu September 30, 1993 October 1, 1993 thru 50,000/MMBtu October 31, 1993 November 1, 1993 thru 50,000/MMBtu November 30, 1993 December 1, 1993 thru 50,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: August 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 23, 1993. Fixed Amount: $2.31/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of August, 1993. $2.33/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of September, 1993. $2.372/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of October, 1993. $2.472/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of November, 1993. $2.60/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of December, 1993. Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 3 Period: Each calendar month beginning with August, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 23, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with August, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with August, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 26, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1569.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.01 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD March 1, 1994 thru 10,000/MMBtu March 31, 1994 April 1, 1994 thru 10,000/MMBtu April 30, 1994 May 1, 1994 thru 10,000/MMBtu May 31, 1994 June 1, 1994 thru 10,000/MMBtu June 30, 1994 July 1, 1994 thru 10,000/MMBtu July 31, 1994 August 1, 1994 thu 10,000/MMBtu August 31, 1994 September 1, 1994 thru 10,000/MMBtu September 30, 1994 October 1, 1994 thru 10,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.0 Page 3 Fixed Amount: $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of March, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of April, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of May, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of June, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of July, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of August, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of September, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: July 14, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 01986.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD August 1, 1993 thru 100,000/MMBtu August 31, 1993 September 1, 1993 thru 50,000/MMBtu September 30, 1993 November 1, 1993 thru 100,000/MMBtu November 30, 1993 December 1, 1993 thru 100,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: August 1,1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month for appropriate delivery month. The first Period End Date being August 31, 1993. Fixed Amount: $2.05/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of August, 1993. $2.075/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of September, 1993. Fixed Amount: $2.33/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of November, 1993. $2.50/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of December, 1993. Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 3 Period: Each calendar month beginning with August, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month for appropriate delivery month. The first Period End Date being August 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with August, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with August, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 4 Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President July 14, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: August 23, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02217.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD December 1, 1993 thru 1,600,000/MMBtu December 31, 1993 January 1, 1994 thru 2,200,000/MMBtu January 31, 1994 February 1, 1994 thru 1,070,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being December 31, 1993. Fixed Amount: $2.575/MMBtu/Dry x 1,600,000 MMBtu per month for the delivery month of December, 1993. $2.535/MMBtu/Dry x 2,200,000 MMBtu per month for the delivery month of January, 1994. $2.355/MMBtu/Dry x 1,070,000 MMBtu per month for the delivery month of February, 1994. Period: Each calendar month beginning with December, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 3 Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being December 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with December, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President August 23, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: August 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02227.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. August 25, 1993 Ref. No.: 02227.00 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD February 1, 1994 thru 1,180,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: February 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being February 28, 1994. Fixed Amount: $2.365/MMBtu/Dry x 1,180,000 MMBtu per month for the delivery month of February, 1994. Period: Each calendar month beginning with February, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being February 28, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with February, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. August 25, 1993 Ref. No.: 02227.00 Page 3 Period: Each calendar month beginning with February, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President August 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 7, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02278.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. September 7, 1993 Ref. No.: 02278.00 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD October 1, 1993 thru 30,000/MMBtu October 31, 1993 November 1, 1993 thru 30,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.285/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of October, 1993. $2.385/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Enron Risk Management Services Corp. September 7, 1993 Ref. No.: 02278.00 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. September 7, 1993 Ref. No.: 02278.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 7, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 10, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02299.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. September 10, 1993 Ref. No.: 02299.00 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.215/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.325/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Enron Risk Management Services Corp. September 10, 1993 Ref. No.: 02299.00 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. September 10, 1993 Ref. No.: 02299.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 10, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 16, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02372.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EEOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. September 16, 1993 Ref. No.: 02372.00 Page 2 QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.105/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.205/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Enron Risk Management Services Corp. September 16, 1993 Ref. No.: 02372.00 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. September 16, 1993 Ref. No.: 02372.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: October 6, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02647.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. October 6, 1993 Ref. No.: 02647.00 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD November 1, 1993 thru 1,650,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: November 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being November 30, 1993. Fixed Amount: $2.18/MMBtu/Dry x 1,650,000 MMBtu per month for the delivery month of November, 1993. Period: Each calendar month beginning with November 30, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being November 30, 1993. Enron Risk Management Services Corp. October 6, 1993 Ref. No.: 02647.00 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with November, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with November, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. October 6, 1993 Ref. No.: 02647.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Title) (Date) Joseph Pokalsky Vice President October 6, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: June 14, 1992 CONFIRMATION ERMS Transaction Reference No.: 0000644 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. Furthermore, this Confirmation cancels and replaces Confirmations 0000302 and 0000332 dated November 15, 1991 and December 17, 1991 respectively. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. June 14, 1992 Ref. No.: 0000644 Page 2 QUANTITY PER PERIOD QUANTITY PER MONTH PERIOD: PER PERIOD January 1, 1996 thru December 31, 2000 40,000 MMBtu "MMBtu" means one million British thermal Units. Effective Date: January 1, 1996 Termination Date: December 31, 2000 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month with the first Period End Date being January 31, 1996. Fixed Amount: $2.42 per MMBtu/Dry x 40,000 MMBtu per day for January 1, 1996 thru December 31, 1999. $2.45 per MMBtu/Dry x 40,000 MMBtu per day for January 1, 2000 thru December 31, 2000. Period: Each calendar month beginning with January, 1996. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month with the first Period End Date being January 31, 1996. Enron Risk Management Services Corp. June 14, 1992 Ref. No.: 0000644 Page 3 Floating Amount: The product of: The Quantity Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with January, 1996. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. June 14, 1992 Ref. No.: 0000644 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Mark Peterson Vice President, Marketing Vice President June 14, 1992 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Manager, Marketing Administration From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: March 25, 1991 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement: Dated As Of: January 1, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOGM") And: Enron Finance Corp. ("EFC") All provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). QUANTITY PER PERIOD QUANTITY PER DAY PERIOD: PER PERIOD (a) April 1991 20,000 MMBtu (b) May 1991 40,000 MMBtu (c) June 1991 through December 1991 60,000 MMBtu (d) January 1992 through December 2000 40,000 MMBtu Enron Oil & Gas Marketing, Inc. March 25, 1991 Page 2 "MMBtu" means one million British thermal units. Effective Date: April 1, 1991 Termination Date: December 31, 2000 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EFC Payment Dates: Three Business Days after each Period Date. Period End Dates: The last day of each calendar month with the first Period End Date being April 30, 1991. Fixed Amount: $_____ ($2.45 per MMBtu x Quantity Per Day Per Period x the number of Days in the Period. Period: Each Calendar month beginning with April 1991. The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EOGM Payment Dates: Twenty-five Business days after each Period End Date. Period End Dates: The last day of each calendar month with the first period End Date being April 30, 1991. Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with April 1991. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following Day which is a New York Banking Day. Enron Oil & Gas Marketing, Inc. March 25, 1991 Page 3 Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds to us, please pay: Citibank, New York, NY; ABA Routing Number 021000089 For the Account of: Enron Corp. for the benefit of Enron Finance Corp. Account Number: 00076486 We will pay you: Through the Fedwire to First City National Bank, Houston, Texas, ABA Routing No. 113000010, for credit to Enron Oil & Gas Marketing, Inc. Account No. 001-00-8640. Each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/750-6831) within three New York Banking Days following receipt of this Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Oil & Gas Marketing, Inc. March 25, 1991 Page 4 Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON FINANCE CORP. By: Name: Mark E. Haedicke Title: Vice President and General Counsel ENRON OIL & GAS MARKETING, INC. By: Name: G. E. Uthlaut Title: Senior Vice President, Operations To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Manager, Marketing Administration From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: April 25, 1991 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement: Dated As Of: March 25, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOGM") And: Enron Finance Corp. ("EFC") All provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. Enron Oil & Gas Marketing, Inc. April 25, 1991 Page 2 The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). QUANTITY PER PERIOD QUANTITY PER DAY PERIOD PER PERIOD (a) April 1991 20,000 MMBtu (b) May 1991 40,000 MMBtu (c) June 1991 through December 1991 60,000 MMBtu (d) January 1992 through December 2000 40,000 MMBtu "MMBtu" means one million British thermal units. Effective Date: April 1, 1991 Termination Date: December 31, 2000 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EFC Payment Dates: On or before the twenty-fifth (25th) day of the calendar month after each Period End Date. Period End Dates: The last day of each calendar month with the first Period End Date being April 30, 1991. Fixed Amount: $_____ ($2.45 per MMBtu x Quantity Per Day Per Period x the number of Days in the Period. Period: Each Calendar month beginning with April 1991. Enron Oil & Gas Marketing, Inc. April 25, 1991 Page 3 The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EOGM Payment Dates: On or before the twenty-fifth (25th) day of the calendar month after each Period End Date. Period End Dates: The last day of each calendar month with the first period End Date being April 30, 1991. Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with April 1991. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds to us, please pay: Hibernia National of New Orleans; ABA Routing Number 065000090 For the Account of: Enron Finance Corp. Account Number: 812141872 We will pay you: Through the Fedwire to NCNB, Houston, Texas, ABA Routing No. 111000025, for credit to Enron Oil & Gas Marketing, Inc. Account No. 414-032-9304. Subject to the netting of cross payments as provided in the master swap agreement, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/750-6831) within three New York Banking Days following receipt of this Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Oil & Gas Marketing, Inc. April 25, 1991 Page 4 Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON FINANCE CORP. By: Name: John J. Esslinger Title: President ENRON OIL & GAS MARKETING, INC. By: Name: Andrew N. Hoyle Title: Vice President, Marketing To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, Texas 77002 Attn: Business Development Dept. From: Enron Finance Corp. 1400 Smith Street Houston, Texas 77002 Date: September 23, 1992 CONFIRMATION EFC Transaction Reference No.: The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: March 25, 1991 Between: Enron Oil & Gas Marketing, Inc. ("EOG") And: Enron Finance Corp. ("EFC") Upon execution, all provisions contained in the master swap agreement govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas"). Enron Finance Corp. September 22, 1992 Ref. No.: Page 2 QUANTITY PER PERIOD: PERIOD QUANTITY PER DAY PERIOD PER PERIOD October 1, 1992 thru 40,000 MMBtu December 31, 1995 "MMBtu" means one million British thermal units. Effective Date: October 1, 1992 Termination Date: December 31, 1995 The terms of this Swap Transaction relating to the Fixed Price Payer are as follows: Fixed Price Payer: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Dates: The last day of each calendar month with the first Period End Date being October 31, 1992. Fixed Amount: $2.45/MMBtu/Dry x 40,000 MMBtu per day for October, 1992 through December, 1995. Period: Each Calendar month beginning with October, 1992. The terms of this Swap Transaction relating to the Floating Price Payer are as follows: Floating Price Payer: EFC Payment Dates: Twenty-five Business days after each Period End Date. Period End Dates: The last day of each calendar month with the first period End Date being October 31, 1992. Enron Finance Corp. September 22, 1992 Ref. No.: Page 3 Floating Amount: The product of: the Quantity Per Day Per Period x the number of Days in the Period x the number determined by subtracting $0.13 from the per MMBtu price reported in the first publication each month of NATURAL GAS WEEK, in the table entitled "Cash Market Hub Trading" as reported for the Current month for Henry Hub, La. Period: Each calendar month beginning with October, 1992. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following Day which is a New York Banking Day. Alternate Component Prices: If NATURAL GAS WEEK is not published for any Period, the Component Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that Period for natural gas delivered to Henry Hub, La. PAYMENT INSTRUCTIONS When remitting funds Nations Bank of Texas to us, please pay: ABA Routing Number 111000025 For the Account of: Enron Finance Corp. Account Number: 414 032 9339 We will pay you: Through the Fedwire to NCNB, Houston, Texas, ABA Routing No. 111000025, for credit to Enron Oil & Gas Marketing, Inc. Account No. 414-032-9304. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgement to such effect to the attention of the Enron Finance Corp. (Fax No. 713/646-3239) within three New York Banking Days following receipt of this Confirmation. Please check this Confirmation carefully upon receipt so that errors and discrepancies can be promptly identified and rectified. Enron Finance Corp. September 22, 1992 Ref. No.: Page 4 Enron Finance Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON FINANCE CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President Date: 9/28/92 September 22, 1992 EX-10.18 7 ISDA MASTER AGREEMENT EXHIBIT 10.18 ISDA International Swap Dealers Association, Inc. MASTER AGREEMENT dated as of November 1, 1993 ENRON OIL & GAS COMPANY and ENRON RISK MANAGEMENT SERVICES CORP. have entered and/or anticipate entering into one or more transactions (each a "Transaction") that are or will be governed by this Master Agreement, which includes the schedule (the "Schedule"), and the documents and other confirming evidence (each a "Confirmation") exchanged between the parties confirming those Transactions. Accordingly, the parties agree as follows:- 1. INTERPRETATION (a) DEFINITIONS. The terms defined in Section 12 and in the Schedule will have the meanings therein specified for the purpose of this Master Agreement. (b) INCONSISTENCY. In the event of any inconsistency between the provisions of the Schedule and the other provisions of this Master Agreement, the Schedule will prevail. In the event of any inconsistency between the provisions of any Confirmation and this Master Agreement (including the Schedule), such Confirmation will prevail for the purpose of the relevant Transaction. (c) SINGLE AGREEMENT. All Transactions are entered into in reliance on the fact that this Master Agreement and all Confirmations form a single agreement between the parties (collectively referred to as this "Agreement"), and the parties would not otherwise enter into any Transactions. 2. OBLIGATIONS (a) GENERAL CONDITIONS. (i) Each party will make each payment or delivery specified in each Confirmation to be made by it, subject to the other provisions of this Agreement. (ii) Payments under this Agreement will be made on the due date for value on that date in the place of the account specified in the relevant Confirmation or otherwise pursuant to this Agreement, in freely transferable funds and in the manner customary for payments in the required currency. Where settlement is by delivery (that is, other than by 1 payment), such delivery will be made for receipt on the due date in the manner customary for the relevant obligation unless otherwise specified in the relevant Confirmation or elsewhere in this Agreement. (iii) Each obligation of each party under Section 2(a)(i) is subject to (1) the condition precedent that no Event of Default or Potential Event of Default with respect to the other party has occurred and is continuing, (2) the condition precedent that no Early Termination Date in respect of the relevant Transaction has occurred or been effectively designated and (3) each other applicable condition precedent specified in this Agreement. (b) CHANGE OF ACCOUNT. Either party may change its account for receiving a payment or delivery by giving notice to the other party at least five Local Business Days prior to the scheduled date for the payment or delivery to which such change applies unless such other party gives timely notice of a reasonable objection to such change. (c) NETTING. If on any date amounts would otherwise be payable:- (i) in the same currency; and (ii) in the respect of the same Transaction, by each party to the other, then, on such date, each party's obligation to make payment of any such amount will be automatically satisfied and discharged and, if the aggregate amount that would otherwise have been payable by one party exceeds the aggregate amount that would otherwise have been payable by the other party, replaced by an obligation upon the party by whom the larger aggregate amount would have been payable to pay to the other party the excess of the larger aggregate amount over the smaller aggregate amount. The parties may elect in respect of two or more Transactions that a net amount will be determined in respect of all amounts payable on the same date in the same currency in respect of such Transactions, regardless of whether such amounts are payable in respect of the same Transaction. The election may be made in the Schedule or a Confirmation by specifying that subparagraph (ii) above will not apply to the Transactions identified as being subject to the election, together with the starting date (in which case subparagraph (ii) above will not, or will cease to, apply to such Transactions from such date). This election may be made separately for different groups of Transactions and will apply separately to each pairing of branches or offices through which the parties make and receive payments or deliveries. (d) DEFAULT INTEREST; OTHER AMOUNTS. Prior to the occurrence or 2 effective designation of an Early Termination Date in respect of the relevant Transaction, a party that defaults in the performance of any payment obligation will, to the extent permitted by law and subject to Section 6(c), be required to pay interest (before as well as after judgment) on the overdue amount to the other party on demand in the same currency as such overdue amount, for the period from (and including) the original due date for payment to (but excluding) the date of actual payment, at the Default Rate. Such interest will be calculated on the basis of daily compounding and the actual number of days elapsed. If, prior to the occurrence or effective designation of an Early Termination Date in respect of the relevant Transaction, a party defaults in the performance of any obligation required to be settled by delivery, it will compensate the other party on demand if and to the extent provided for in the relevant Confirmation or elsewhere in this Agreement. 3. REPRESENTATIONS Each party represents to the other party (which representations will be deemed to be repeated by each party on each date on which a Transaction is entered into) that:- (a) BASIC REPRESENTATIONS. (i) STATUS. It is duly organized and validly existing under the laws of the jurisdiction of its organisation or incorporation and, if relevant under such laws, in good standing; (ii) POWERS. It has the power to execute this Agreement and any other documentation relating to this Agreement to which it is a party, to deliver this Agreement and any other documentation relating to this Agreement that it is required by this Agreement to deliver and to perform its obligations under this Agreement and any obligations it has under any Credit Support Document to which it is a party and has taken all necessary action to authorize such execution, delivery and performance; (iii) NO VIOLATION OR CONFLICT. Such execution, delivery and performance do not violate or conflict with any law applicable to it, any provision of its constitutional documents, any order or judgment of any court or other agency of government applicable to it or any of its assets or any contractual restriction binding on or affecting it or any of its assets; (iv) CONSENTS. All governmental and other consents that are required to have been obtained by it with respect to this Agreement or any Credit Support Document to which it is a party have been obtained and are in full force and effect and all conditions of any such consents have been complied with; and 3 (v) OBLIGATIONS BINDING. Its obligations under this Agreement and any Credit Support Document to which it is a party constitute its legal, valid and binding obligations, enforceable in accordance with their respective terms (subject to applicable bankruptcy, reorganisation, insolvency, moratorium or similar laws affecting creditors' rights generally and subject, as to enforceability, to equitable principles of general application (regardless of whether enforcement is sought in a proceeding in equity or at law)). (b) ABSENCE OF CERTAIN EVENTS. No Event of Default or Potential Event of Default or, to its knowledge, Termination Event with respect to it has occurred and is continuing and no such event or circumstance would occur as a result of its entering into or performing its obligations under this Agreement or any Credit Support Document to which it is a party. (c) ABSENCE OF LITIGATION. There is not pending or, to its knowledge, threatened against it or any of its Affiliates any action, suit or proceeding at law or in equity or before any court, tribunal, governmental body, agency or official or any arbitrator that is likely to affect the legality, validity or enforceability against it of this Agreement or any Credit Support Document to which it is a party or its ability to perform its obligations under this Agreement or such Credit Support Document. (d) ACCURACY OF SPECIFIED INFORMATION. All applicable information that is furnished in writing by or on behalf of it to the other party and is identified for the purpose of this Section 3 (d) in the Schedule is, as of the date of the information, true accurate and complete in every material respect. 4. AGREEMENTS Each party agrees with the other that, so long as either party has or may have any obligation under this Agreement or under any Credit Support Document to which it is a party:- (a) FURNISH SPECIFIED INFORMATION. It will deliver to the other party any forms, documents or certificates specified in the Schedule or any Confirmation by the date specified in the Schedule or such Confirmation or, if none is specified, as soon as reasonably practicable. (b) MAINTAIN AUTHORIZATIONS. It will use all reasonable efforts to maintain in full force and effect all consents of any governmental or other authority that are required to be obtained by it with respect to this Agreement or any Credit Support Document to which it is a party and will use all reasonable efforts to obtain any that may become necessary in the future. (c) COMPLY WITH LAWS. It will comply in all material respects with 4 all applicable laws and orders to which it may be subject if failure so to comply would materially impair its ability to perform its obligations under this Agreement or any Credit Support Document to which it is a party. 5. EVENTS OF DEFAULT AND TERMINATION EVENTS (a) EVENTS OF DEFAULT. The occurrence at any time with respect to a party or, if applicable, any Credit Support Provider of such party or any Specified Entity of such party of any of the following events constitutes an event of default (an "Event of Default") with respect to such party:- (i) FAILURE TO PAY OR DELIVER. Failure by the party to make, when due, any payment under this Agreement or delivery under Section 2(a)(i) or 2(d) required to be made by it if such failure is not remedied on or before the third Local Business Day after notice of such failure is given to the party; (ii) BREACH OF AGREEMENT. Failure by the party to comply with or perform any agreement or obligation (other than an obligation to make any payment under this Agreement or delivery under Section 2(a)(i) or 2(d) or to give notice of a Termination Event or any agreement or obligation under Section 4(a)) to be complied with or performed by the party in accordance with this Agreement if such failure is not remedied on or before the thirtieth day after notice of such failure is given to the party; (iii) CREDIT SUPPORT DEFAULT. (1) Failure by the party or any Credit Support Provider of such party to comply with or perform any agreement or obligation to be complied with or performed by it in accordance with any Credit Support Document if such is continuing after any applicable grace period has elapsed; (2) the expiration or termination of such Credit Support Document or the failing or ceasing of such Credit Support Document to be in full force and effect for the purpose of this Agreement (in either case other than in accordance with its terms) prior to the satisfaction of all obligations of such party under each Transaction to which such Credit Support Document relates without the written consent of the other party; or (3) the party or such Credit Support Provider disaffirms, disclaims, repudiates or rejects, in whole or in part, or challenges the validity of, such Credit Support Document; 5 (iv) MISREPRESENTATION. A representation made or repeated or deemed to have been made or repeated by the party or any Credit Support Provider of such party in this Agreement or any Credit Support Document proves to have been incorrect or misleading in any material respect when made or repeated or deemed to have been made or repeated; (v) DEFAULT UNDER SPECIFIED TRANSACTION. The party, any Credit Support Provider of such party or any applicable Specified Entity of such party (1) defaults under a Specified Transaction and, after giving effect to any applicable notice requirement or grace period, there occurs a liquidation of, an acceleration of obligations under, or an early termination of that Specified Transaction, (2) defaults, after giving effect to any applicable notice requirement or grace period, in making any payment or delivery due on the last payment, delivery or exchange date of, or any payment on early termination of, a Specified Transaction (or such default continues for at least three Local Business Days if there is no applicable notice requirement or grace period) or (3) disaffirms, disclaims, repudiates or rejects, in whole or in part, a Specified Transaction (or such action is taken by any person or entity appointed or empowered to operate it or act on its behalf); (vi) CROSS DEFAULT. If "Cross Default" is specified in the Schedule as applying to the party, the occurrence or existence of (1) a default, event of default or other similar condition or event (however described) in respect of such party, any Credit Support Provider of such party or any applicable Specified Entity of such party under one or more agreements or instruments relating to Specified Indebtedness of any of them (individually or collectively) in an aggregate amount of not less than this applicable Threshold Amount (as specified in the Schedule) which has resulted in such Specified Indebtedness becoming, or becoming capable at such time of being declared, due and payable under such agreements or instruments, before it would otherwise have been due and payable or (2) a default by such party, such Credit Support Provider or such Specified Entity (individually or collectively) in making one or more payments on the due date thereof in an aggregate amount of not less than the applicable Threshold Amount under such agreements or instruments (after giving effect to any applicable notice requirement or grace period); (vii) BANKRUPTCY. The party, any Credit Support Provider of such party or any applicable Specified Entity of such party:- (1) is dissolved (other than pursuant to a consolidation, amalgamation or merger); (2) becomes insolvent or is unable to pay its debts of fails or admits in writing its 6 inability generally to pay its debts as they become due; (3) makes a general assignment, arrangement or composition with or for the benefit of its creditors; (4) institutes or has instituted against it a proceeding seeking a judgment of insolvency or bankruptcy or any other relief under any bankruptcy or insolvency law or other similar law affecting creditors' rights, or a petition is presented for its winding-up or liquidation, and, in the case of any such proceeding or petition instituted or presented against it, such proceeding or petition (A) results in a judgment or insolvency or bankruptcy or the entry of an order for relief or the making of an order for its winding-up or liquidation or (B) is not dismissed, discharged, stayed or restrained in each case within 30 days of the institution or presentation thereof; (5) has a resolution passed for its winding-up, official management or liquidation (other than pursuant to a consolidation, amalgamation or merger); (6) seeks or becomes subject to the appointment of an administrator, provisional liquidator, conservator, receiver, trustee, custodian or other similar official for it or for all or substantially all its assets; (7) has a secured party take possession of all or substantially all its assets or has a distress, execution, attachment, sequestration or other legal process levied, enforced or sued on or against all or substantially all its assets and such secured party maintains possession, or any such process is not dismissed, discharged, stayed or restrained, in each case within 30 days thereafter; (8) causes or is subject to any event with respect to it which, under the applicable laws or any jurisdiction, has an analogous effect to any of the events specified in clauses (1) to (7) (inclusive); or (9) takes any action in furtherance of, or indicating its consent to, approval of, or acquiescence in, any of the foregoing acts; or (viii) MERGER WITHOUT ASSUMPTION. The party of any Credit Support Provider of such party consolidates or amalgamates with, or merges with or into, or transfers all or substantially all its assets to, another entity and, at the time of such consolidation, amalgamation, merger or transfer:- (1) the resulting, surviving or transferee entity fails to assume all the obligations of such party or such Credit Support Provider under this Agreement or any Credit Support Document to which it or its predecessor was a party by operation of law or pursuant to an agreement reasonably satisfactory to the other party to this Agreement; or (2) the benefits of any Credit Support Document fail to extend (without the consent of the other party) to the 7 performance by such resulting, surviving or transferee entity of its obligations under this Agreement. (b) TERMINATION EVENTS. The occurrence at any time with respect to a party or, if applicable, any Credit Support Provider of such party or any Specified Entity of such party of any event specified below constitutes an Illegality if the event is specified in (i) below, and, if specified to be applicable, a Credit Event Upon Merger if the event is specified pursuant to (ii) below or an Additional Termination Event if the Event is specified pursuant to (iii) below:- (i) ILLEGALITY. Due to the adoption of, or any change in, any applicable law after the date on which a Transaction is entered into, or due to the promulgation of, or any change in, the interpretation by any court, tribunal or regulatory authority with competent jurisdiction of any applicable law after such date, it becomes unlawful (other than as a result of a breach by the party of Section 4(b) for such party (which will be the Affected Party):- (1) to perform any absolute or contingent obligation to make a payment or delivery or to receive a payment or delivery in respect of such Transaction or to comply with any other material provision of this Agreement relating to such Transaction; or (2) to perform, or for any Credit Support Provider of such party to perform, any contingent or other obligation which the party (or such Credit Support Provider) has under any Credit Support Document relating to such Transaction; (ii) CREDIT EVENT UPON MERGER. If "Credit Event Upon Merger" is specified in the Schedule as applying to the party, such party ("X"), any Credit Support Provider of X or any applicable Specified Entity of X consolidates or amalgamates with, or merges with or into, or transfers all or substantially all its assets to, another entity and such action does not constitute an event described in Section 5(a)(viii) but the creditworthiness of the resulting, surviving or transferee entity is materially weaker than that of X, such Credit Support Provider or such Specified Entity, as the case may be, immediately prior to such action (and, in such event, X or its successor or transferee, as appropriate, will be the Affected Party); or (iii) ADDITIONAL TERMINATION EVENT. If any "Additional Termination Event" is specified in the Schedule or any Confirmation as applying, the occurrence of such event (and, in such event, the Affected Party or Affected Parties shall be as specified for such Additional Termination Event in the 8 Schedule or such Confirmation). (c) EVENT OF DEFAULT AND ILLEGALITY. If an event or circumstance which would otherwise constitute or give rise to an Event of Default also constitutes an Illegality, it will be treated as an Illegality and will not constitute an Event of Default. 6. EARLY TERMINATION (a) RIGHT TO TERMINATE FOLLOWING EVENT OF DEFAULT. If at any time an Event of Default with respect to a party (the "Defaulting Party") has occurred and is then continuing, the other party (the "Non-Defaulting Party") may, by not more than 20 days notice to the Defaulting Party specifying the relevant Event of Default, designate a day not earlier than the day such notice is effective as an Early Termination Date in respect of all outstanding Transactions. If, however, "Automatic Early Termination" is specified in the Schedule as applying to a party, then an Early Termination Date in respect of all outstanding Transactions will occur immediately upon the occurrence with respect to such party of an Event of Default specified in Section 5(a)(vii)(1), (3), (5), (6) or, to the extent analogous thereto, (8), and as of the time immediately preceding the institution of the relevant proceeding or the presentation of the relevant petition upon the occurrence with respect to such party of an Event of Default specified in Section 5(a)(vii)(4) or, to the extent analogous thereto, (8). (b) RIGHTS TO TERMINATE FOLLOWING TERMINATION EVENT. (i) NOTICE. If a Termination Event occurs, an Affected Party will, promptly upon becoming aware of it notify the other party, specifying the nature of that Termination Event and each Affected Transaction and will also give such other information about that Termination Event as the other party may reasonably require. (ii) TWO AFFECTED PARTIES. If an Illegality under Section 5(b)(1) occurs and there are two Affected Parties, each party will use all reasonable efforts to reach agreement within 30 days after notice thereof is given under Section 6(b)(i) on action to avoid that Termination Event. (iii) RIGHTS TO TERMINATE. If:- (1) an agreement under section 6(b)(ii) has not been effected with respect to all Affected Transactions within 30 days after an Affected Party gives notice under Section 6(b)(i); or (2) an Illegality other than that referred to in Section 6(b)(ii), a Credit Event Upon Merger or an Additional Termination Event occurs, 9 either party in the case of an Illegality, any Affected Party in the case of an Additional Termination Event if there is more than one Affected Party, or the party which is not the Affected Party in the case of a Credit Event Upon Merger or an Additional Termination Event if there is only one Affected Party may, by not more than 20 days notice to the other party and provided that the relevant Termination Event is then continuing, designate a day not earlier than the day such notice is effective as an Early Termination Date in respect of all Affected Transactions. (c) EFFECT OF DESIGNATION. (i) If notice designating an Early Termination Date is given under Section 6(a) or (b), the Early Termination Date will occur on the date so designated, whether or not the relevant Event of Default or Termination Event is then continuing. (ii) Upon the occurrence of effective designation of an Early Termination Date, no further payments or deliveries under Section 2(a)(i) or 2(d) in respect of the Terminated Transactions will be required to be made, but without prejudice to the other provisions of this Agreement. The amount, if any, payable in respect of an Early Termination Date shall be determined pursuant to Section 6(e). (d) CALCULATIONS. (i) STATEMENT. On or as soon as reasonably practicable following the occurrence of an Early Termination Date, each party will make the calculations on its part, if any, contemplated by Section 6(e) and will provide to the other party a statement (1) showing, in reasonable detail, such calculations (including all relevant quotations and specifying any amount payable under Section 6(e)) and (2) giving details of the relevant account to which any amount payable to it is to be paid. In the absence of written confirmation from the source of a quotation obtained in determining a Market Quotation, the records of the party obtaining such quotation will be conclusive evidence of the existence and accuracy of such quotation. (ii) PAYMENT DATE. An amount calculated as being due in respect of any Early Termination Date under Section 6(e) will be payable on the day that notice of the amount payable is effective (in the case of an Early Termination Date which is designated or occurs as a result of an Event of Default) and on the day which is two Local Business Days after the day on which notice of the amount payable is effective (in the case of an Early Termination Date which is designated as a result of a Termination Event). Such amount will be paid together with (to the extent permitted under applicable law) interest 10 thereon (before as well as after judgment), from (and including) the relevant Early Termination Date to (but excluding) the date such amount is paid, at the Applicable Rate. Such interest will be calculated on the basis of daily compounding and the actual number of days elapsed. (e) PAYMENTS ON EARLY TERMINATION. If an Early Termination Date occurs, the following provisions shall apply based on the parties' election in the Schedule of a payment measure, either "Market Quotation" or "Loss", and a payment method, either the "First Method" or the "Second Method". If the parties fail to designate a payment measure or payment method in the Schedule, it will be deemed that "Market Quotation" or the "Second Method", as the case may be, shall apply. The amount, if any, payable in respect of an Early Termination Date and determined pursuant to this Section will be subject to any Set-off. (i) EVENTS OF DEFAULT. If the Early Termination Date results from an Event of Default:- (1) FIRST METHOD AND MARKET QUOTATION. If the First Method and Market Quotation apply, the Defaulting Party will pay to the Non-defaulting Party the excess, if a positive number, of (A) the sum of the settlement Amount (determined by the Non-defaulting Party) in respect of the Terminated Transactions and the Unpaid Amounts owing to the Non- defaulting Party over (B) the Unpaid Amounts owing to the Defaulting Party. (2) FIRST METHOD AND LOSS. If the First Method and Loss apply, the Defaulting Party will pay to the Non- defaulting Party, if a positive number, the Non- defaulting Party's Loss in respect of this Agreement. (3) SECOND METHOD AND MARKET QUOTATION. If the Second Method and Market Quotation apply, an amount will be payable equal to (A) the sum of the Settlement Amount (determined by the Non-defaulting Party) in respect to the Termination Transactions and the Unpaid Amounts owing to the Non- defaulting Party less (B) the Unpaid Amounts owing to the Defaulting Party. If that amount is a positive number, the Defaulting Party will pay it to the Non-defaulting Party; if it is a negative number, the Non-defaulting Party will pay the absolute value of that amount to the Defaulting Party. (4) SECOND METHOD AND LOSS. If the Second Method and Loss apply, an amount will be payable equal to the Non-defaulting Party's Loss in respect of this Agreement. If that amount is a positive number, the Defaulting Party will pay it to the Non-defaulting Party; if it is a negative number, the Non-defaulting Party will pay the 11 absolute value of that amount to the Defaulting Party. (ii) TERMINATION EVENTS. If the Early Termination Date results from a Termination Event:- (1) ONE AFFECTED PARTY. If there is one Affected Party, the amount payable will be determined in accordance with Section 6(e)(i)(3), if Market Quotation applies, or Section 6(e)(i)(4), if Loss applies, except that, in either case, references to the Defaulting Party and to the Non-defaulting Party will be deemed to be references to the Affected Party and the party which is not the Affected Party, respectively, and, if Loss applies and fewer than all the Transactions are being terminated, Loss shall be calculated in respect of all Terminated Transactions. (2) TWO AFFECTED PARTIES. If there are two Affected Parties:- (A) if Market Quotation applies, each party will determine a Settlement Amount in respect of the Terminated Transactions, and an amount will be payable equal to (I) the sum of (a) one-half of the difference between the Settlement Amount of the party with the higher Settlement Amount ("X") and the Settlement Amount of the party with the lower Settlement Amount ("Y") and (b) the Unpaid Amounts owing to X less (II) the Unpaid Amounts owing to Y; and (B) if Loss applies, each party will determine its Loss in respect of this Agreement (or, if fewer than all the transactions are being terminated, in respect of all Terminated Transactions) and an amount will be payable equal to one-half of the difference between the Loss of the party with the higher Loss ("X") and the Loss of the party with the lower Loss ("Y"). If the amount payable is a positive number, Y will pay it to X; if it a negative number, X will pay the absolute value of that amount to Y. (iii) ADJUSTMENT FOR BANKRUPTCY. In circumstances where an Early Termination Date occurs because "Automatic Early Termination" applies in respect of a party, the amount determined under this Section 6(e) will be subject to such adjustments as are appropriate and permitted by law to reflect any payments or deliveries made by one party to the other under this Agreement (and retained by such other party) during the period from the relevant Early Termination Date to the 12 date for payment determined under Section 6(d)(ii). (iv) PRE-ESTIMATE. The parties agree that if Market Quotation applies an amount recoverable under this Section 6(e) is a reasonable pre-estimate of loss and not a penalty. Such amount is payable for the loss of bargain and the loss of protection against future risks and except as otherwise provided in this Agreement neither party will be entitled to recover any additional damages as a consequence of such losses. 7. TRANSFER Neither this Agreement nor any obligation in or under this Agreement may be transferred (whether by way of security or otherwise) by either party without the prior written consent of the other party, except that:- (a) a party may make such a transfer of this Agreement pursuant to a consolidation or amalgamation with, or merger with or into, or transfer of all or substantially all its assets to, another entity (but without prejudice to any other right or remedy under this Agreement); and (b) a party may make such a transfer of all or any part of its interest in any amount payable to it from a Defaulting Party under Section 6(e). Any purported transfer that is not in compliance with this Section will be void. 8. MISCELLANEOUS (a) ENTIRE AGREEMENT. This Agreement constitutes the entire agreement and understanding of the parties with respect to its subject matter and supersedes all oral communication and prior writings with respect thereto. (b) AMENDMENTS. No amendment, modification or waiver in respect of this Agreement will be effective unless in writing (including a writing evidenced by a facsimile transmission) and executed by each of the parties or confirmed by an exchange of telexes or electronic messages on an electronic messaging system. (c) SURVIVAL OF OBLIGATIONS. Without prejudice to Section 2(a)(iii) and 6(c)(ii), the obligations of the parties under this Agreement will survive the termination of any Transaction. (d) REMEDIES CUMULATIVE. Except as provided in this Agreement, the rights, powers remedies and privileges provided in this Agreement are cumulative and not exclusive of any rights, powers, remedies and privileges provided by law. 13 (e) COUNTERPARTS AND CONFIRMATIONS. (i) This Agreement (and each amendment, modification and waiver in respect of it) may be executed and delivered in counterparts (including by facsimile transmission), each of which will be deemed an original. (ii) The parties intend that they are legally bound by the terms of each Transaction from the moment they agree to those terms (whether orally or otherwise). A Confirmation shall be entered into as soon as practicable and may be executed and delivered in counterparts (including by facsimile transmission) or created by an exchange of telexes or by an exchange of electronic messages on an electronic messaging system, which in each case will be sufficient for all purposes to evidence a binding supplement to this Agreement. The parties will specify therein or through another effective means that any such counterpart, telex or electronic message constitutes a Confirmation. (f) NO WAIVER OF RIGHTS. A failure or delay in exercising any right, power or privilege in respect of this Agreement will not be presumed to operate as a waiver, and a single or partial exercise of any right, power or privilege will not be presumed to preclude any subsequent or further exercise, of that right, power or privilege or the exercise of any other right, power or privilege. (g) HEADINGS. The headings used in this Agreement are for convenience of reference only and are not to affect the construction of or to be taken into consideration in interpreting this Agreement. 9. EXPENSES A Defaulting Party will, on demand, indemnify and hold harmless the other party for and against all reasonable out-of-pocket expenses, including legal fees, incurred by such other party by reason of the enforcement and protection of its rights under this Agreement or any Credit Support Document to which the Defaulting Party is a party or by reason of the early termination of any Transaction, including, but not limited to, costs of collection. 10. NOTICES (a) EFFECTIVENESS. Any notice or other communication in respect of this Agreement may be given in any manner set forth below (except that a notice or other communication under Section 5 or 6 may not be given by facsimile transmission or electronic messaging system) to the address or number or in accordance with the electronic messaging system details provided (see the Schedule) and will be deemed effective as indicated:- 14 (i) if in writing and delivered in person or by courier, on the date it is delivered: (ii) if sent by telex, on the date the recipient's answerback is received. (iii) if sent by facsimile transmission, on the date that transmission is received by a responsible employee of the recipient in legible form (it being agreed that the burden of proving receipt will be on the sender and will not be met by a transmission report generated by the sender's facsimile machine); (iv) if sent by certified or registered mail (airmail, if overseas) or the equivalent (return receipt requested), on the date that mail is delivered or its delivery is attempted; or (v) if sent by electronic messaging system, on the date that electronic message is received, unless the date of delivery (or attempted deliver) or that receipt, as applicable, is not a Local Business Day or that communication is delivered (or attempted) or received, as applicable, after the close of business on a Local Business Day, in which case that communication shall be deemed given and effective on the first following day that is a Local Business Day. (b) CHANGE OF ADDRESSES. Either party may by notice to the other change the address, telex or facsimile number or electronic messaging system details at which notices or other communications are to be given to it. 11. GOVERNING LAW AND JURISDICTION (a) GOVERNING LAW. This Agreement will be governed by and construed in accordance with the law specified in the Schedule. (b) JURISDICTION. With respect to any suit, action or proceedings relating to this Agreement ("Proceedings"), each party irrevocably:- (i) submits to the jurisdiction of the English courts, if this Agreement is expressed to be governed by English law, or to the non-exclusive jurisdiction of the courts of the State of New York and the United States District Court located in the Borough of Manhattan in New York City, if this Agreement is expressed to be governed by the laws of the State of New York; and (ii) waives any objection which it may have at any time to the laying of venue of any Proceedings brought in any such court, waives any claim that such Proceedings have been brought in an 15 inconvenient forum and further waives the right to object, with respect to such proceedings, that such court does not have any jurisdiction over such party. Nothing in this Agreement precludes either party from bringing Proceedings in any other jurisdiction (outside, if this Agreement is expressed to be governed by English law, the Contracting States, as defined in Section 1(3) of the Civil Jurisdiction and Judgments Act 1982 or any modification, extension or re-enactment thereof for the time being in force) nor will the bringing of Proceedings in any one or more jurisdictions preclude the bringing of Proceedings in any other jurisdiction. (c) WAIVER OF IMMUNITIES. Each party irrevocably waives, to the fullest extent permitted by applicable law, with respect to itself and its revenues and assets (irrespective of their use or intended use), all immunity on the grounds of sovereignty or other similar grounds from (i) suit, (ii) jurisdiction of any court, (iii) relief by way of injunction, order for specific performance or for recovery of property, (iv) attachment of its assets (whether before or after judgment) and (v) execution or enforcement of any judgment to which it or its revenues or assets might otherwise be entitled in any Proceedings in the courts of any jurisdiction and irrevocably agrees, to the extent permitted by applicable law, that it will not claim any such immunity in any Proceedings. 12. DEFINITIONS As used in this Agreement:- "Additional Termination Event" has the meaning specified in Section 5(b). "Affected Party" has the meaning specified in Section 5(b). "Affected Transactions" means (a) with respect to any Termination Event consisting of an Illegality, all Transactions affected by the occurrence of such Termination Event and (b) with respect to any other Termination Event, all Transactions. "Affiliate" means, subject to the Schedule, in relation to any person, any entity controlled, directly or indirectly, by the person, any entity that controls, directly or indirectly, the person or any entity directly or indirectly under common control with the person. For this purpose, "control" of any entity or person means ownership of a majority of the voting power of the entity or person. "Applicable Rate" means:- (a) in respect of obligations payable or deliverable (or which would have been but for Section 2(a)(iii)) by a Defaulting Party, the Default Rate; 16 (b) in respect of an obligation to pay an amount under Section 6(a) of either party from and after the date (determined in accordance with Section 6(d)(ii) on which that amount is payable, the Default Rate; (c) in respect of all other obligations payable or deliverable (or which would have been but for Section 2(a)(iii)) by a Non-defaulting Party, the Non-default Rate; and (d) in all other cases, the Termination Rate. "consent" includes a consent, approval, action, authorisation, exemption, notice, filing, registration or exchange control consent. "Credit Event Upon Merger" has the meaning specified in Section 5(b). "Credit Support Document" means any agreement or instrument that is specified as such in this Agreement. "Credit Support Provider" has the meaning specified in the Schedule. "Default Rate" means a rate per annum equal to the cost (without proof or evidence of any actual cost) to the relevant payee (as certified by it) if it were to fund or of funding the relevant amount plus 1% per annum. "Defaulting Party" has the meaning specified in Section 6(a). "Early Termination Date" means the date determined in accordance with Section 6(a) or 6(b)(iii). "Event of Default" has the meaning specified in Section 5(a) and, if applicable, in the Schedule. "Illegality" has the meaning specified in Section 5(b). "law" includes any treaty, law, rule or regulation and "LAWFUL" and "UNLAWFUL" will be construed accordingly. "Local Business Day" means, subject to the Schedule, a day on which commercial banks are open for business (including dealings in foreign exchange and foreign currency deposits) (a) in relation to any obligation under Section 2(a)(i), in the place(s) specified in the relevant Confirmation or, if not so specified, as otherwise agreed by the parties in writing or determined pursuant to provisions contained, or incorporated by reference, in this Agreement, (b) in relation to any other payment, in the place where the relevant account is located, (c) in relation to any notice or other communication, including notice contemplated under Section 17 5(a)(i), in the city specified in the address for notice provided by the recipient and, in the case of a notice contemplated by Section 2(b), in the place where the relevant new account is to be located and (d) in relation to Section 5(a)(v)(2), in the relevant locations for performance with respect to such Specified Transaction. "Loss" means, with respect to this Agreement or one or more Terminated Transactions, as the case may be, and a party, an amount that party reasonably determines in good faith to be its total losses and costs (or gain, in which case expressed as a negative number) in connection with this Agreement or that Terminated Transaction or group of Terminated Transactions, as the case may be, including any loss or bargain, cost of funding or, at the election of such party but without duplication, loss or cost incurred as a result of its terminating, liquidating, obtaining or reestablishing any hedge or related trading position (or any gain resulting from any of them). Loss includes losses and costs (or gains) in respect of any payment or delivery required to have been made (assuming satisfaction of each applicable condition precedent) on or before the relevant Early Termination Date and not made, except, so as to avoid duplication, if Section 6(e)(i)(1) or (3) or 6(e)(ii)(2)(A) applies. Loss does not include a party's legal fees and out-of-pocket expenses referred to under Section 9. A party will determine its Loss as of the relevant Early Termination Date, or, if that is not reasonably practicable, as of the earliest date thereafter as it reasonably practicable. A party may (but need not) determine its Loss by reference to quotations of relevant rates or prices from one or more leading dealers in the relevant markets. "Market Quotation" means, with respect to one or more Terminated Transactions and a party making the determination, an amount determined on the basis of quotation from Reference Market-makers. Each quotation will be for an amount, if any, that would be paid to such party (expressed as a negative number) or by such party (expressed as a positive number) in consideration of an agreement between such party (taking into account any existing Credit Support Document with respect to the obligations of such party) and the quoting Reference Market-maker to enter into a transaction (the "Replacement Transaction") that would have the effect of preserving for such party the economic equivalent of any payment or delivery (whether the underlying obligation was absolute or contingent and assuming the satisfaction of each applicable condition precedent) by the parties under Section 2(a)(i) in respect of such Terminated Transaction or group of Terminated Transactions that would, but for the occurrence of the relevant Early Termination Date, have been required after that date. For this purpose, Unpaid Amounts in respect of the Terminated Transaction or group of Terminated Transactions are to be excluded but, without limitation, any payment or delivery that would, but for the relevant Early Termination Date, have been required (assuming satisfaction of each 18 applicable condition precedent) after that Early Termination Date is to be included. The Replacement Transaction would be subject to such documentation as such party and the Reference Market-maker may, in good faith, agree. The party making the determination (or its agent) will request each Reference Market-maker to provide its quotation to the extent reasonably practicable as of the same day and time (without regard to different time zones) on or as soon as reasonably practicable after the relevant Early Termination Date. The day and time as of which those quotations are to be obtained will be selected in good faith by the party obliged to make a determination under Section 6(e), and, if each party is so obliged, after consultation with the other. If more than three quotations are provided, the Market Quotation will be the arithmetic mean of the quotations, without regard to the quotations having the highest and lowest values. If exactly three such quotations are provided, the Market Quotation will be the quotation remaining after disregarding the highest and lowest quotations. For this purpose, if more than one quotation has the same highest value or lowest value, then one of such quotations shall be disregarded. If fewer than three quotations are provided, it will be deemed that the Market Quotation in respect of such Terminated Transaction or group of Terminated Transactions cannot be determined. "Non-default Rate" means a rate per annum equal to the cost (without proof or evidence of any actual cost) to the Non-defaulting Party (as certified by it) if it were to fund the relevant amount. "Non-defaulting Party" has the meaning specified in Section 6(a). "Potential Event of Default" means any event which, with the giving of notice or the lapse of time or both, would constitute an Event of Default. "Reference Market-makers" means four leading dealers in the relevant market selected by the party determining a Market Quotation in good faith (a) from among dealers of the highest credit standing which satisfy all the criteria that such party applies generally at the time in deciding whether to offer or to make an extension of credit and (b) to the extent practicable, from among such dealers having an office in the same city. "Scheduled Payment Date" means a date on which a payment or delivery is to be made under Section 2(a)(i) with respect to a Transaction. Set-off" means set-off, offset, combination of accounts, right of retention or withholding or similar right or requirement to which the player of an amount under Section 6 is entitled or subject (whether arising under this Agreement, another contract, applicable law or otherwise) that is exercised by, or imposed on, such payer. 19 "Settlement Amount" means, with respect to a party and any Early Termination Date, the sum of:- (a) the Market Quotation (whether positive or negative) for each Terminated Transaction or group of Terminated Transactions for which a Market Quotation is determined; and (b) such party's Loss (whether positive or negative and without reference to any Unpaid Amounts) for each Terminated Transaction or group of Terminated Transactions for which a Market Quotation cannot be determined or would not (in the reasonable belief of the party making the determination) produce a commercially reasonable result. "Specified Entity" has the meaning specified in the Schedule. "Specified Indebtedness" means, subject to the Schedule, any obligation (whether present or future, contingent or otherwise, as principal or surety or otherwise) in respect of borrowed money. "Specified Transaction" means, subject to the Schedule, (a) any transaction (including an agreement with respect thereto) now existing or hereafter entered into between one party to this Agreement (or any Credit Support Provider of such party or any applicable Specified Entity of such party) and the other party to this Agreement (or any Credit Support Provider of such other party or any applicable Specified Entity of such other party) which is a rate swap transaction, basis swap, forward rate transaction, commodity swap, commodity option, equity or equity index swap, equity or equity index option, bond option, interest rate option, foreign exchange transaction, cap transaction, floor transaction, collar transaction, currency swap transaction, cross-currency rate swap transaction, currency option or any other similar transaction (including any option with respect to any of these transactions), (b) any combination of these transactions and (c) any other transaction identified as a Specified Transaction in this Agreement or the relevant confirmation. "Terminated Transactions" means with respect to any Early Termination Date (a) if resulting from a Termination Event, all Affected Transactions and (b) if resulting from an Event of Default, all Transactions (in either case) in effect immediately before the effectiveness of the notice designating that Early Termination Date (or, if "Automatic Early Termination" applies, immediately before that Early Termination Date). "Termination Event" means an Illegality or, if specified to be applicable, a Credit Event Upon Merger or an Additional Termination Event. "Termination Rate" means a rate per annum equal to the arithmetic mean of the cost (without proof or evidence of any actual cost) to 20 each party (as certified by such party) if it were to fund or of funding such amounts. "Unpaid Amounts" owing to any party means, with respect to an Early Termination Date, the aggregate of (a) in respect of all Terminated Transactions, the amounts that became payable (or that would have become payable but for Section 2(a)(iii)) to such party under Section 2(a)(i) on or prior to such Early Termination Date and which remain unpaid as at such Early Termination Date and (b) in respect of each Terminated Transaction, for each obligation under Section 2(a)(i) which was (or would have been but for Section 2(a)(iii)) required to be settled by delivery to such party on or prior to such Early Termination Date and which has not been so settled as at such Early Termination Date, an amount equal to the fair market value of that which was (or would have been) required to be delivered as of the originally scheduled date for delivery, in each case together with (to the extent permitted under applicable law) interest, in the currency of such amounts, from (and including) the date such amounts or obligations were or would have been required to have been paid or performed to (but excluding) such Early Termination Date, at the Applicable Rate. Such amounts of interest will be calculated on the basis of daily compounding and the actual number of days elapsed. The fair market value of any obligation referred to in clause (b) above shall be reasonably determined by the party obliged to make the determination under Section 6(e) or, if each party is so obliged, it shall be the average of the fair market values reasonably determined by both parties. IN WITNESS WHEREOF the parties have executed this document on the respective dates specified below with effect from the date specified on the first page of this document. ENRON OIL & GAS COMPANY (Name of Party) BY: Name: George E. Uthlaut Title: Sr. Vice President, Operations Date: November 9, 1993 ENRON RISK MANAGEMENT SERVICES CORP. (Name of Party) 21 BY: Name: Lou L. Pai Title: President Date: November 9, 1993 22 ISDA INTERNATIONAL SWAP DEALERS ASSOCIATION, INC. SCHEDULE TO THE MASTER AGREEMENT DATED AS OF NOVEMBER ____, 1993 BETWEEN ENRON OIL & GAS COMPANY AND ENRON RISK MANAGEMENT SERVICES CORP. ("Party A") ("Party B") Part l. TERMINATION PROVISIONS. (a) "SPECIFIED ENTITY" means in relation to Party A for the purpose of:-- Section5 (a)(v), Section 5(a)(vi), Section 5(a)(vii), Section 5(b)(ii), AND IN RELATION TO PARTY B FOR THE PURPOSE OF: Section 5(a)(v), Section 5(a)(vi), Section 5(a)(vii), Section 5(b)(ii), (b) "SPECIFIED TRANSACTION" will have the meaning specified in Section 12 of this Agreement unless another meaning is specified here (c) THE "CROSS DEFAULT" provisions of Section 5(a)(vi) will apply to Party A will apply to Party B If such provisions apply:-- "SPECIFIED INDEBTEDNESS" will have the meaning specified in Section 12 of this Agreement unless another meaning is specified here "THRESHOLD AMOUNT" means a) as to Party A, $25,000,000, and b) as to Party B $10,000,000. (d) THE "CREDIT EVENT UPON MERGER" provisions of Section 5(b)(ii) will apply to Party A will apply to Party B (e) THE "AUTOMATIC EARLY TERMINATION" provision of Section 6(a) will apply to Party A will apply to Party B (f) PAYMENTS ON EARLY TERMINATION. For the purpose of Section 6(e) of this Agreement:-- (i) Market Quotation will apply (ii) The Second Method will apply (g) ADDITIONAL TERMINATION EVENT will not apply. The following shall constitute an Additional Termination Event:-- For the purpose of the foregoing Termination Event, the Affected Party or Affected Parties shall be:-- Part 2. AGREEMENT TO DELIVER DOCUMENTS. For the purpose of Section 4(a) of this Agreement, each party agrees to deliver the following documents, as applicable:-- PARTY REQUIRED FORM/DOCUMENT/ DATE BY WHICH COVERED BY TO DELIVERY CERTIFICATE TO BE DELIVERED SECTION 3(D) DOCUMENT REPRESENTATION Yes/No Yes/No Yes/No Yes/No Yes/No Part 3. MISCELLANEOUS (a) ADDRESSES FOR NOTICES. For the purpose of Section 10(a) of this Agreement:-- Addresses for notices or communications to Party A:-- Address: 1400 Smith Street, Houston, Texas 77002 Attention: Director, Marketing Administration Telex No.: Answerback: Facsimile No: (713) 646-2113 Telephone No.: Electronic Messaging System Details: Address for notices or communications to PartyB:-- Address: 1400 Smith Street, Houston, Texas 77002 Attention: Administration (Trading) Telex No.: 765443 Answerback: ENRONCORP Facsimile No. (713) 646-3239 Telephone No.: Electronic Messaging System Details: None (b) CALCULATION AGENT. The Calculation Agent is PARTY B unless otherwise specified in a Confirmation in relation to the relevant Transaction. (c) CREDIT SUPPORT DOCUMENT. Details of any Credit Support Document:- See Part 4 (d) CREDIT SUPPORT PROVIDER. Credit Support Provider means in relation to Party A. Credit Support Provider means in relation to Party B. (e) GOVERNING LAW. This Agreement will be governed by and construed in accordance with the laws of the State of Texas (without reference to choice of law doctrine). (f) NETTING OF PAYMENTS. Subparagraph (ii) of Section 2(c) of this Agreement will not apply to the Transactions. (g) "Affiliate" will have the meaning specified in Section 12 of this Agreement unless another meaning is specified here Part 4. OTHER PROVISIONS 1. CREDIT SUPPORT DOCUMENT - To the extent the majority of the capital stock of any party is no longer owned by Enron Corp. (either directly or indirectly), the other party may require the first party to provide a Credit Support Document as security for the performance of the first party's obligations hereunder. Such Credit Support Document shall be reasonably acceptable to the other party. To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 10, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1268.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 10, 1993 Ref. No.: 1268.0 Page 2 Quantity Per PERIOD QUANTITY PER MONTH Period: PER PERIOD March 1, 1993 thru 120,000/MMBtu March 31, 1993 April 1, 1993 thru 510,000/MMBtu April 30, 1993 May 1, 1993 thru 580,000/MMBtu May 31,1993 June 1, 1993 thru 750,000/MMBtu June 30, 1993 July 1, 1993 thru 0/MMBtu July 31, 1993 August 1, 1993 thru 750,000/MMBtu August 31, 1993 September 1, 1993 thru 530,000/MMBtu September 30, 1993 October 1, 1993 thru 750,000/MMBtu October 31, 1993 November 1, 1993 thru 750,000/MMBtu November 30, 1993 December 1, 1993 thru 750,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. February 10, 1993 Ref. No.: 1268.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Fixed Amount: $1.715/MMBtu/Dry x 120,000 MMBtu per month for the delivery month of March, 1993. $1.712/MMBtu/Dry x 510,000 MMBtu per month for the delivery month of April, 1993. $1.71/MMBtu/Dry x 580,000 MMBtu per month for the delivery month of May, 1993. $1.71/MMBtu/Dry x 750,000 MMBtu per month for the delivery month of June, 1993. $0.00/MMBtu/Dry x 0 MMBtu per month for the delivery month of July, 1993. $1.755/MMBtu/Dry x 750,000 MMBtu per month for the delivery month of August, 1993. $1.785/MMBtu/Dry x 530,000 MMBtu per month for the delivery month of September, 1993. $1.915/MMBtu/Dry x 750,000 MMBtu per month for the delivery month of October, 1993. $2.075/MMBtu/Dry x 750,000 MMBtu per month for the delivery month of November, 1993. $2.25/MMBtu/Dry x 750,000 MMBtu per month for the delivery month of December, 1993. Period: Each calendar month beginning with March, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. February 10, 1993 Ref. No.: 1268.0 Page 4 Period: Each calendar month beginning with March, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 10, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 12, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1286.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 2 Quantity Per PERIOD QUANTITY PER DAY Period: PER PERIOD March 1, 1993 thru 30,000/MMBtu March 31, 1993 April 1, 1993 thru 30,000/MMBtu April 30, 1993 May 1, 1993 thru 30,000/MMBtu May 31,1993 June 1, 1993 thru 30,000/MMBtu June 30, 1993 July 1, 1993 thru 30,000/MMBtu July 31, 1993 August 1, 1993 thru 30,000/MMBtu August 31, 1993 September 1, 1993 thru 30,000/MMBtu September 30, 1993 October 1, 1993 thru 30,000/MMBtu October 31, 1993 November 1, 1993 thru 30,000/MMBtu November 30, 1993 December 1, 1993 thru 30,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Fixed Amount: $1.72/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of March, 1993. $1.715/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of April, 1993. $1.697/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of May, 1993. $1.712/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of June, 1993. $1.715/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of July, 1993. $1.743/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of August, 1993. $1.775/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of September, 1993. $1.926/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of October, 1993. $2.084/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of November, 1993. $2.278/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with March, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. February 12, 1993 Ref. No.: 1286.0 Page 4 Period: Each calendar month beginning with March, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 12, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 16, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1291.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period January 1, 1994 thru 60,000/MMBtu January 31, 1994 February 1, 1994 thru 60,000/MMBtu February 28, 1994 Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 2 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.276/MMBtu/Dry x 60,000 MMBtu per day for the delivery month of January, 1994. $1.988/MMBtu/Dry x 60,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1291.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 16, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1292.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period April 1, 1993 thru 45,000/MMBtu April 30, 1993 May 1, 1993 thru 45,000/MMBtu May 31,1993 June 1, 1993 thru 45,000/MMBtu June 30, 1993 July 1, 1993 thru 45,000/MMBtu July 31, 1993 August 1, 1993 thru 45,000/MMBtu August 31, 1993 September 1, 1993 thru 45,000/MMBtu September 30, 1993 October 1, 1993 thru 45,000/MMBtu October 31, 1993 November 1, 1993 thru 45,000/MMBtu November 30, 1993 December 1, 1993 thru 45,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 3 Fixed Amount: $1.739/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of April, 1993. $1.72/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of May, 1993. $1.719/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of June, 1993. $1.719/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of July, 1993. $1.738/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of August, 1993. $1.763/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of September, 1993. $1.918/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of October, 1993. $2.076/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of November, 1993. $2.274/MMBtu/Dry x 45,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. February 16, 1993 Ref. No.: 1292.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 17, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1304.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period April 1, 1993 thru 25,000/MMBtu April 30, 1993 May 1, 1993 thru 25,000/MMBtu May 31,1993 June 1, 1993 thru 25,000/MMBtu June 30, 1993 July 1, 1993 thru 25,000/MMBtu July 31, 1993 August 1, 1993 thru 25,000/MMBtu August 31, 1993 September 1, 1993 thru 25,000/MMBtu September 30, 1993 October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 December 1, 1993 thru 25,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 3 Fixed Amount: $1.76/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of April, 1993. $1.742/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of May, 1993. $1.734/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of June, 1993. $1.736/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of July, 1993. $1.744/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of August, 1993. $1.77/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of September, 1993. $1.926/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.075/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. $2.266/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1304.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 17, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1305.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period January 1, 1994 thru 55,000/MMBtu January 31, 1994 February 1, 1994 thru 55,000/MMBtu February 28, 1994 Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 2 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.282/MMBtu/Dry x 55,000 MMBtu per day for the delivery month of January, 1994. $1.993/MMBtu/Dry x 55,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with January, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 3 Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 17, 1993 Ref. No.: 1305.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 19, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1321.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period January 1, 1994 thru 10,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: January 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Fixed Amount: $2.265/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of January, 1994. $1.99/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with January, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 3 Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being December 22, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with January, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 19, 1993 Ref. No.: 1321.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 19, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 23, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1335.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period April 1, 1993 thru 25,000/MMBtu April 30, 1993 May 1, 1993 thru 25,000/MMBtu May 31,1993 June 1, 1993 thru 25,000/MMBtu June 30, 1993 July 1, 1993 thru 25,000/MMBtu July 31, 1993 August 1, 1993 thru 25,000/MMBtu August 31, 1993 September 1, 1993 thru 25,000/MMBtu September 30, 1993 October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 December 1, 1993 thru 20,000/MMBtu December 31, 1993 January 1, 1994 thru 20,000/MMBtu January 31, 1994 February 1, 1994 thru 15,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: April 1, 1993 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Fixed Amount: $1.856/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of April, 1993. $1.794/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of May, 1993. $1.755/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of June, 1993. $1.745/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of July, 1993. $1.75/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of August, 1993. $1.77/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of September, 1993. $1.915/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.083/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. $2.26/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of December, 1993. $2.26/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of January, 1994. $1.985/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1335.0 Page 5 Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 23, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: February 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1338.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 23, 1993 Ref. No.: 1338.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period December 1, 1993 thru 5,000/MMBtu December 31, 1993 January 1, 1994 thru 5,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Fixed Amount: $2.24/MMBtu/Dry x 5,000 MMBtu per day for the delivery month of December, 1993. $2.24/MMBtu/Dry x 5,000 MMBtu per day for the delivery month of January, 1994. $1.975/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. Period: Each calendar month beginning with December, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1338.0 Page 3 Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with January, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1338.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: March 12, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1370.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. February 25, 1993 Ref. No.: 1370.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period May 1, 1993 thru 15,000/MMBtu May 31,1993 June 1, 1993 thru 15,000/MMBtu June 30, 1993 July 1, 1993 thru 15,000/MMBtu July 31, 1993 August 1, 1993 thru 15,000/MMBtu August 31, 1993 September 1, 1993 thru 15,000/MMBtu September 30, 1993 October 1, 1993 thru 15,000/MMBtu October 31, 1993 November 1, 1993 thru 15,000/MMBtu November 30, 1993 December 1, 1993 thru 10,000/MMBtu December 31, 1993 January 1, 1994 thru 10,000/MMBtu January 31, 1994 February 1, 1994 thru 10,000/MMBtu February 28, 1994 March 1, 1994 15,000/MMBtu thru March 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: May 1, 1993 Termination Date: March 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 3 Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being April 23, 1993. Fixed Amount: $1.895/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of May, 1993. $1.842/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of June, 1993. $1.82/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of July, 1993. $1.815/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of August, 1993. $1.82/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of September, 1993. $1.92/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of October, 1993. $2.07/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of November, 1993. $2.235/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of December, 1993. $2.235/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of January, 1994. $1.985/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of February, 1994. $1.815/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of March, 1994. Period: Each calendar month beginning with May, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being April 23, 1993. Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 4 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with May, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with May, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. March 12, 1993 Ref. No.: 1370.0 Page 5 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President March 12, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 6, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1471.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period December 1, 1993 thru 7,500/MMBtu December 31, 1993 January 1, 1994 thru 20,000/MMBtu January 31, 1994 Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 2 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: January 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 22, 1993. Fixed Amount: $2.41/MMBtu/Dry x 7,500 MMBtu per day for the delivery month of December, 1993. $2.375/MMBtu/Dry x 20,000 MMBtu per day for the delivery month of January, 1994. Period: Each calendar month beginning with December, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being November 19, 1993. Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 3 Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with December, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1471.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. (Title) (Date) Lou L. Pai Vice President April 6, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1485.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 6, 1993 Ref. No.: 1485.0 Page 2 Quantity Per Period Quantity Per Month Period: Per Period March 1, 1994 thru 155,000/MMBtu March 31, 1994 April 1, 1994 thru 150,000/MMBtu April 30, 1994 May 1, 1994 thru 155,000/MMBtu May 31, 1994 June 1, 1994 thru 150,000/MMBtu June 30, 1994 July 1, 1994 thru 155,000/MMBtu July 31, 1994 August 1, 1994 thru 155,000/MMBtu August 31, 1994 September 1, 1994 thru 150,000/MMBtu September 30, 1994 October 1, 1994 thru 155,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 3 Fixed Amount: $2.091/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of March, 1994. $2.066/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of April, 1994. $2.076/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of May, 1994. $2.086/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of June, 1994. $2.096/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of July, 1994. $2.101/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of August, 1994. $2.108/MMBtu/Dry x 150,000 MMBtu per month for the delivery month of September, 1994. $2.176/MMBtu/Dry x 155,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. March 13, 1993 Ref. No.: 1485.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1486.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc.(EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period June 1, 1993 thru 10,000/MMBtu June 30, 1993 July 1, 1993 thru 10,000/MMBtu July 31, 1993 August 1, 1993 thru 10,000/MMBtu August 31, 1993 September 1, 1993 thru 10,000/MMBtu September 30, 1993 October 1, 1993 thru 10,000/MMBtu October 31, 1993 November 1, 1993 thru 10,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: June 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 3 Fixed Amount: $2.259/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of June, 1993. $2.233/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of July, 1993. $2.243/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of August, 1993. $2.252/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of September, 1993. $2.31/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of October, 1993. $2.422/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with April, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being March 24, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with April, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1486.0 Page 4 reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President February 17, 1993 [DATE] To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1494.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 2 Quantity Per Period Quantity Per Month Period: Per Period March 1, 1994 thru 620,000/MMBtu March 31, 1994 April 1, 1994 thru 600,000/MMBtu April 30, 1994 May 1, 1994 thru 620,000/MMBtu May 31, 1994 June 1, 1994 thru 600,000/MMBtu June 30, 1994 July 1, 1994 thru 620,000/MMBtu July 31, 1994 August 1, 1994 thru 620,000/MMBtu August 31, 1994 September 1, 1994 thru 600,000/MMBtu September 30, 1994 October 1, 1994 thru 620,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 3 Fixed Amount: $2.125/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of March, 1994. $2.085/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of April, 1994. $2.095/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of May, 1994. $2.11/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of June, 1994. $2.11/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of July, 1994. $2.11/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of August, 1994. $2.12/MMBtu/Dry x 600,000 MMBtu per month for the delivery month of September, 1994. $2.20/MMBtu/Dry x 620,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1494.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1495.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period June 1, 1993 thru 10,000/MMBtu June 30, 1993 July 1, 1993 thru 10,000/MMBtu July 31, 1993 August 1, 1993 thru 10,000/MMBtu August 31, 1993 September 1, 1993 thru 10,000/MMBtu September 30, 1993 October 1, 1993 thru 10,000/MMBtu October 31, 1993 November 1, 1993 thru 10,000/MMBtu November 30, 1993 "MMBtu" means one million British thermal Units. Effective Date: June 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 3 Fixed Amount: $2.35/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of June, 1993. $2.33/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of July, 1993. $2.33/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of August, 1993. $2.35/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of September, 1993. $2.38/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of October, 1993. $2.49/MMBtu/Dry x 10,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with June, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being May 21, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with June, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with June, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely Enron Risk Management Services Corp. April 13, 1993 Ref. No.: 1495.0 Page 4 reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 13, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 13, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1509.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period August 1, 1994 thru 15,000/MMBtu August 31, 1994 September 1, 1994 thru 15,000/MMBtu September 30, 1994 Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 2 "MMBtu" means one million British thermal Units. Effective Date: August 1, 1994 Termination Date: September 30, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 22, 1994 Fixed Amount: $2.235/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of August, 1994. $2.23/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of September, 1994. Period: Each calendar month beginning with August, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 22, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with June, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 3 Period: Each calendar month beginning with August, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. April 14, 1993 Ref. No.: 1509.0 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Lou L. Pai Vice President, Marketing Vice President April 14, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 15, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 1514.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period March 1, 1994 thru 15,000/MMBtu March 31, 1994 April 1, 1994 thru 15,000/MMBtu April 30, 1994 May 1, 1994 thru 15,000/MMBtu May 31, 1994 June 1, 1994 thru 15,000/MMBtu June 30, 1994 July 1, 1994 thru 15,000/MMBtu July 31, 1994 October 1, 1994 thru 15,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 3 Fixed Amount: $2.245/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of March, 1994. $2.21/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of April, 1994. $2.223/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of May, 1994. $2.235/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of June, 1994. $2.245/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of July, 1994. $2.315/MMBtu/Dry x 15,000 MMBtu per day for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the Enron Risk Management Services Corp. April 15, 1993 Ref. No.: 1514.0 Page 4 mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 15, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 26, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1533.01 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 2 Quantity Per Period Quantity Per Day Period: Per Period August 1, 1993 thru 50,000/MMBtu August 31, 1993 September 1, 1993 thru 50,000/MMBtu September 30, 1993 October 1, 1993 thru 50,000/MMBtu October 31, 1993 November 1, 1993 thru 50,000/MMBtu November 30, 1993 December 1, 1993 thru 50,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: August 1, 1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 23, 1993. Fixed Amount: $2.31/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of August, 1993. $2.33/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of September, 1993. $2.372/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of October, 1993. $2.472/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of November, 1993. $2.60/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of December, 1993. Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 3 Period: Each calendar month beginning with August, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being July 23, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with August, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with August, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed Enron Risk Management Services Corp. April 26, 1993 Ref. No.: 1533.01 Page 4 by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 26, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: April 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 1569.0 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.0 Page 2 Quantity Per Period Quantity Per Day Period: Per Period March 1, 1994 thru 10,000/MMBtu March 31, 1994 April 1, 1994 thru 10,000/MMBtu April 30, 1994 May 1, 1994 thru 10,000/MMBtu May 31, 1994 June 1, 1994 thru 10,000/MMBtu June 30, 1994 July 1, 1994 thru 10,000/MMBtu July 31, 1994 August 1, 1994 thu 10,000/MMBtu August 31, 1994 September 1, 1994 thru 10,000/MMBtu September 30, 1994 October 1, 1994 thru 10,000/MMBtu October 31, 1994 "MMBtu" means one million British thermal Units. Effective Date: March 1, 1994 Termination Date: October 31, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: ERMS Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.0 Page 3 Fixed Amount: $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of March, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of April, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of May, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of June, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of July, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of August, 1994. $2.269/MMBtu/Dry x 300,000 MMBtu per month for the delivery month of September, 1994. $2.269/MMBtu/Dry x 310,000 MMBtu per month for the delivery month of October, 1994. Period: Each calendar month beginning with March, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: EOG Payment Dates: 25th calendar day succeeding each Period End Date. Period End Date: The last NYMEX Trading Day for the natural gas contract for the appropriate delivery month. The first Period End Date being February 18, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month of beginning with March, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with March, 1994. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Enron Risk Management Services Corp. April 25, 1993 Ref. No.: 1569.0 Page 4 Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President April 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: July 14, 1993 REVISED CONFIRMATION LETTER ERMS Transaction Reference No.: 01986.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 2 Quantity Per Period Quantity Per Day Period: Per Period August 1, 1993 thru 100,000/MMBtu August 31, 1993 September 1, 1993 thru 50,000/MMBtu September 30, 1993 November 1, 1993 thru 100,000/MMBtu November 30, 1993 December 1, 1993 thru 100,000/MMBtu December 31, 1993 "MMBtu" means one million British thermal Units. Effective Date: August 1,1993 Termination Date: December 31, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month for appropriate delivery month. The first Period End Date being August 31, 1993. Fixed Amount: $2.05/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of August, 1993. $2.075/MMBtu/Dry x 50,000 MMBtu per day for the delivery month of September, 1993. Fixed Amount: $2.33/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of November, 1993. $2.50/MMBtu/Dry x 100,000 MMBtu per day for the delivery month of December, 1993. Period: Each calendar month beginning with August, 1993. Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 3 The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last day of each calendar month for appropriate delivery month. The first Period End Date being August 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with August, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with August, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. Enron Risk Management Services Corp. July 14, 1993 Ref. No.: 01986.00 Page 4 The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President July 14, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: August 23, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02217.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 2 Quantity Per Period Quantity Per Month Period: Per Period December 1, 1993 thru 1,600,000/MMBtu December 31, 1993 January 1, 1994 thru 2,200,000/MMBtu January 31, 1994 February 1, 1994 thru 1,070,000/MMBtu February 28, 1994 "MMBtu" means one million British thermal Units. Effective Date: December 1, 1993 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being December 31, 1993. Fixed Amount: $2.575/MMBtu/Dry x 1,600,000 MMBtu per month for the delivery month of December, 1993. $2.535/MMBtu/Dry x 2,200,000 MMBtu per month for the delivery month of January, 1994. $2.355/MMBtu/Dry x 1,070,000 MMBtu per month for the delivery month of February, 1994. Period: Each calendar month beginning with December, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 3 Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being December 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with December, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with December, 1993. Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. August 23, 1993 Ref. No.: 02217.00 Page 4 Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President August 23, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: August 25, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02227.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Month Period: Per Period February 1, 1994 thru 1,180,000/MMBtu February 28, 1994 Enron Risk Management Services Corp. August 25, 1993 Ref. No.: 02227.00 Page 2 "MMBtu" means one million British thermal Units. Effective Date: February 1, 1994 Termination Date: February 28, 1994 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being February 28, 1994. Fixed Amount: $2.365/MMBtu/Dry x 1,180,000 MMBtu per month for the delivery month of February, 1994. Period: Each calendar month beginning with February, 1994. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being February 28, 1994. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with February, 1994 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with February, 1994. Enron Risk Management Services Corp. August 25, 1993 Ref. No.: 02227.00 Page 3 Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President August 25, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 7, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02278.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period October 1, 1993 thru 30,000/MMBtu October 31, 1993 November 1, 1993 thru 30,000/MMBtu November 30, 1993 Enron Risk Management Services Corp. September 7, 1993 Ref. No.: 02278.00 Page 2 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.285/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of October, 1993. $2.385/MMBtu/Dry x 30,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Enron Risk Management Services Corp. September 7, 1993 Ref. No.: 02278.00 Page 3 Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 7, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 10, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02299.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 Enron Risk Management Services Corp. September 10, 1993 Ref. No.: 02299.00 Page 2 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.215/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.325/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Enron Risk Management Services Corp. September 10, 1993 Ref. No.: 02299.00 Page 3 Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 10, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: September 16, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02372.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Day Period: Per Period October 1, 1993 thru 25,000/MMBtu October 31, 1993 November 1, 1993 thru 25,000/MMBtu November 30, 1993 Enron Risk Management Services Corp. September 16, 1993 Ref. No.: 02372.00 Page 2 "MMBtu" means one million British thermal Units. Effective Date: October 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Fixed Amount: $2.105/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of October, 1993. $2.205/MMBtu/Dry x 25,000 MMBtu per day for the delivery month of November, 1993. Period: Each calendar month beginning with October 31, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being October 31, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with October, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with October, 1993. Enron Risk Management Services Corp. September 16, 1993 Ref. No.: 02372.00 Page 3 Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President September 16, 1993 To: Enron Oil & Gas Marketing, Inc. 1400 Smith Street Houston, TX 77002 Attn: Business Development Dept. From: Enron Risk Management Services Corp. 1400 Smith Street Houston, TX 77002 Date: October 6, 1993 CONFIRMATION LETTER ERMS Transaction Reference No.: 02647.00 The purpose of this communication is to set forth the terms and conditions of the Swap Transaction entered into between us as of the Effective Date specified below (the "Swap Transaction"). This communication constitutes a "Confirmation" as referred to in the master swap agreement specified below. The definitions and provisions contained in the 1987 Interest Rate and Currency Exchange Definitions (as published by the International Swap Dealers Association, Inc.) are incorporated into this Confirmation. In the event of any inconsistency between those definitions and provisions and this Confirmation, this Confirmation will govern. Each party represents that it is entering into this transaction in connection with its line of business and that the terms hereof have been individually tailored and negotiated. This Confirmation supplements, forms part of, and is subject to, the following master swap agreement upon execution thereof: Dated As Of: June 1, 1991 Between: Enron Oil & Gas Marketing, Inc. (EOG) And: Enron Risk Management Services Corp. (ERMS) Upon execution, all provisions contained in the master swap agreement will govern this Confirmation except as expressly modified below. The terms of the particular Swap Transaction to which this Confirmation relates are as follows: Commodity: Pipeline quality natural gas ("Natural Gas") Quantity Per Period Quantity Per Month Period: Per Period November 1, 1993 thru 1,650,000/MMBtu November 30, 1993 Enron Risk Management Services Corp. October 6, 1993 Ref. No.: 02647.00 Page 2 "MMBtu" means one million British thermal Units. Effective Date: November 1, 1993 Termination Date: November 30, 1993 The terms of this Swap Transaction relating to the Fixed Price Payor are as follows: Fixed Price Payor: EOG Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being November 30, 1993. Fixed Amount: $2.18/MMBtu/Dry x 1,650,000 MMBtu per month for the delivery month of November, 1993. Period: Each calendar month beginning with November 30, 1993. The terms of this Swap Transaction relating to the Floating Price Payor are as follows: Floating Price Payor: ERMS Payment Dates: Twenty-five days after each Period End Date. Period End Date: The last calendar day for the appropriate delivery month. The first Period End Date being November 30, 1993. Floating Amount: The product of: The Quantity Per Period x the average of the settlement prices for the natural gas contract on the New York Mercantile Exchange for the appropriate delivery month beginning with November, 1993 for the last three NYMEX Trading Days for the natural gas contract for that month of delivery. Period: Each calendar month beginning with November, 1993. Enron Risk Management Services Corp. October 6, 1993 Ref. No.: 02647.00 Page 3 Banking Day Convention: If any specified Payment Date is not a New York Banking Day such Payment Date will be the first following day which is a New York Banking Day. Alternate Component Prices: If NYMEX Natural Gas Settlement Prices are not published for any Period, the Price for such Period shall be the amount determined by the mutual agreement of the parties in good faith to most closely reflect the average spot price in Dollars per MMBtu for that period for natural gas delivered to Henry Hub, LA. Subject to the netting of cross payments as provided in the master swap agreement referred to herein, each party has agreed to make payments to the other in accordance with this Confirmation. Please confirm that the foregoing correctly sets forth the terms of our agreement by sending a return acknowledgment to such effect to the attention of the Enron Risk Management Services Corp. (Fax No. 713/646-3564) within three New York Banking Days following this Confirmation. The parties agree that this Swap Transaction will be governed by and subject to the terms and conditions of a master swap agreement upon execution thereof. Please check this Confirmation carefully upon receipt so that errors and discrepancies can promptly be identified and rectified. Enron Risk Management Services Corp. is very pleased to have concluded this transaction with you. Regards, ENRON OIL & GAS MARKETING, INC. ENRON RISK MANAGEMENT SERVICES CORP. Andrew N. Hoyle Joseph Pokalsky Vice President, Marketing Vice President October 6, 1993 EX-10.36.B 8 FIRST AMENDMENT TO CONVEYANCE OF PRODUCTION EXHIBIT 10.36(b) FIRST AMENDMENT TO CONVEYANCE OF PRODUCTION PAYMENT Reference for all purposes is hereby made to that certain Conveyance of Production Payment (the "Conveyance"), dated September 25, 1992, from ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") to CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), pertaining to certain oil and gas leases, wells and related interests, which Conveyance is recorded as set forth on Exhibit C hereto under the caption "Conveyance of Production Payment." WHEREAS, Grantor and Grantee desire to amend the Conveyance as hereinafter set forth as of April 1, 1993 (the "Effective Date") to release certain Leases and Subject Wells from the Conveyance and to add certain additional oil and gas leases and related interests and to make other changes as provided herein: NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars and no/100ths ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Conveyance as follows: 1. Capitalized terms as used herein shall have the meanings given to them in Article II of the Conveyance unless otherwise defined herein. 2. Exhibit A to the Conveyance is hereby amended by deleting those Leases set forth on Exhibit A-1 hereto (the "Deleted Leases") and those Subject Wells set forth on Exhibit A-2 hereto (the "Deleted Wells") and adding those oil and gas leases and related interests set forth on Exhibit B hereto (the "Added Leases"). 3. Grantee hereby releases the Deleted Leases and the Deleted Wells from the Conveyance and hereby grants, reconveys and delivers unto Grantor, its successors and assigns, without recourse, covenant or warranty of any kind, express, implied or statutory, the Production Payment insofar and only insofar as the Production Payment covers or applies to the Deleted Leases and the Deleted Wells. Grantor hereby grants, conveys and delivers unto Grantee, its successors and assigns, the Production Payment described in the Conveyance as hereby amended in accordance with the terms and provisions of the Conveyance as hereby amended. 4. Except as expressly amended hereby, the Conveyance shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Conveyance as hereby amended. EXECUTED in multiple originals this 21st day of May, 1993, but effective as of the Effective Date. GRANTOR: WITNESSES: ENRON OIL & GAS COMPANY By: Name: D. Weaver Title: Agent and Attorney-in-fact GRANTEE: WITNESSES: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp. General Partner By: Name: Andrew S. Fastow Title: Vice President EXHIBIT "A-1" - Description of Deleted Leases EXHIBIT "A-2" - Description of Deleted Wells EXHIBIT "B" - Description of Added Leases EXHIBIT "C" - Recordation Schedule - Conveyance of Production Payment STATE OF TEXAS COUNTY OF HARRIS On this _____ day of _____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ________________________, to me personally known, who, being by me duly sworn, did say that he is the ___________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, and that the instrument was signed in behalf of the corporation by authority of its Board of Directors and that ____________________ acknowledged the instrument to be the free act and deed of the corporation. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary STATE OF TEXAS COUNTY OF HARRIS On this _____ day of ____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ______________________, to me personally known, who, being by me duly sworn, did say that he is the ________________ of Enron Big Piney Corp., General Partner of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, and that the instrument was signed on behalf of said corporation, acting as General Partner of said limited partnership and that _________________________ acknowledged the instrument to be the free act and deed of the limited partnership. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary EXHIBIT A-1 Attached to and made a part of that certain First Amendment to Conveyance of Production Payment effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED LEASES SUBLETTE COUNTY, WYOMING
ENRON LEASE LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDING 0050097-000 EV-023584 TOWNSHIP 28 NORTH, RANGE 113 WEST, 6TH P.M. 6/1/48 Not Recorded Section 23: Lot 4 (27.24), W/2NW/4 Below 1500' above the top of the Frontier formation 0050109-000 State WY- TOWNSHIP 29 NORTH, RANGE 113 WEST, 6TH P.M. 9/16/48 Not Recorded 07395 Section 16: E/2 Below 1500' above the top of the Frontier formation 0050115-000 WY-04732 TOWNSHIP 28 NORTH, RANGE 113 WEST, 6TH P.M. 2/1/51 Not Recorded Section 4: Lots 7 (35.76), 8 (36.27), S/2NW/4, SW/4 Below 1500' above the top of the Frontier formation 0050116-000 W-026038-A TOWNSHIP 29 NORTH, RANGE 113 WEST, 6TH P.M. 2/1/50 BK 31, PG 206 Section 21: E/2 Section 27: NW/4NW/4 Section 28: N/2NE/4 Below 1500' above the top of the Frontier formation 0050125-000 McGinnis, TOWNSHIP 28 NORTH, RANGE 113 WEST, 6TH P.M. 7/1/46 BK 2, PG 101 Mary et al Section 27: Resurvey Tract 48 From 1500' above the top of the Frontier formation to the base of the Frontier formation LINCOLN COUNTY, WYOMING 0050272-000 EV-09156-B TOWNSHIP 26 NORTH, RANGE 113 WEST, 6TH P.M. 6/1/48 BK 17, PG 283 Section 5: E/2SE/4 No depth limitations
EXHIBIT A-2 Attached to and made a part of that certain First Amendment to Conveyance of Production Payment effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED WELLS
WELL WELL LEGAL W I NRI WI NRI NAME NUMBER DESCRIPTION BPO BPO APO APO SHU 65-05G 06152-00-00-1 TOWNSHIP 26 NORTH, RANGE 25.000% 20.350% 25.000% 20.3500% 113 WEST, 6TH P.M. Section 5: E/2 Lincoln County, Wyoming Tip Top Unit 06144-00-00-1 TOWNSHIP 27 NORTH, RANGE 1.4233% 1.0870% 1.4233% 1.0870% Participating 113 WEST, 6TH P.M. Area "B" Parts of Sections 5 and 6 TOWNSHIP 28 NORTH, RANGE 113 WEST, 6TH P.M. Portions of Sections 6-8, 16, 17 and 18 TOWNSHIP 28 NORTH, RANGE 114 WEST, 6TH P.M. Portions of Sections 1 and 12 Sublette County, Wyoming
EXHIBIT B Attached to and made a part of that certain First Amendment to Conveyance of Production Payment effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. ADDED LEASES SUBLETTE COUNTY, WYOMING
MOBIL LEASE LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDING W-2645 E-025771 TOWNSHIP 28 NORTH, RANGE 113 WEST, 1/1/48 Not Available 6TH P.M. Section 22: Lot 2 (23.91) From the surface to 1500' above the top of the Frontier formation W-2579 E-023969 TOWNSHIP 28 NORTH, RANGE 113 WEST, 7/1/48 Not Available 6TH P.M. Section 27: Lots 2 (13.62), 3 (9.19) Section 29: W/2NW/4 From the surface to 1500' above the top of the Frontier formation W-2571 E-023768 TOWNSHIP 28 NORTH, RANGE 113 WEST, 12/1/47 BK 31, PG 429 6TH P.M. Section 20: SW/4SW/4 From the surface to 1500' above the top of the Frontier formation W-2569 E-022879 TOWNSHIP 28 NORTH, RANGE 113 WEST, 7/1/47 Not Available 6TH P.M. Section 19: Lots 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16 and 17 From the surface to 1500' above the top of the Frontier formation W-2568 E-023328 TOWNSHIP 28 NORTH, RANGE 113 WEST, 10/1/48 Not Available 6TH P.M. Section 30: N/2NE/4 From the surface to 1500' above the top of the Frontier formation W-2566 E-023553 TOWNSHIP 28 NORTH, RANGE 113 WEST, 6/1/48 Not Available 6TH P.M. Section 30: S/2NE/4 From the surface to 1500' above the top of the Frontier formation W-2586 W-01495 TOWNSHIP 28 NORTH, RANGE 113 WEST, 2/1/50 Not Available 6TH P.M. Section 18: Lots 11, 12, 13, 14, 15, 16, 17, 18 (W/2SE/4) From the surface to 1500' above the top of the Frontier formation
EXHIBIT C Attached to and made a part of that certain First Amendment to Conveyance of Production Payment effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DOCUMENT FILING ENTITY RECORDING REFERENCE Conveyance of Production Payment dated Lincoln County Book 317 PR, Page 312 September 25, 1992 from EOG to Cactus File No. 755518 October 8, 1992 Sublette County Book 89 O&G, Page 512 File No. 238874 October 2, 1992 BLM October 2, 1992 Wyoming State November 20, 1992 Land Board EX-10.36.C 9 SECOND AMENDMENT TO CONVEYANCE OF PRODUCTION EXHIBIT 10.36(c) SECOND AMENDMENT TO CONVEYANCE OF PRODUCTION PAYMENT Reference for all purposes is hereby made to that certain Conveyance of Production Payment dated September 25, 1992, from ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") to CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), as amended by that certain First Amendment to Conveyance of Production Payment dated effective April 1, 1993, between Grantor and Grantee (the "Conveyance"), pertaining to certain oil and gas leases, wells and related interests, which Conveyance is recorded as set forth on Exhibit C hereto. WHEREAS, Grantor and Grantee desire to amend the Conveyance as hereinafter set forth as of July 1, 1993 (the "Effective Date") to release certain Leases and Subject Wells from the Conveyance and to add certain additional oil and gas leases, wells and related interests and to make other changes as provided herein: NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars and no/100ths ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Conveyance as follows: 1. Capitalized terms as used herein shall have the meanings given to them in Article II of the Conveyance unless otherwise defined herein. 2. Exhibit A to the Conveyance is hereby amended by deleting those Leases set forth on Exhibit A-1 hereto (the "Deleted Leases") and those Subject Wells set forth on Exhibit A-2 hereto (the "Deleted Wells") and adding those oil and gas leases and related interests set forth on Exhibit B-1 hereto (the "Added Leases") and those wells set forth on Exhibit B-2 hereto (the "Added Wells"). 3. Grantee hereby releases the Deleted Leases and the Deleted Wells from the Conveyance and hereby grants, reconveys and delivers unto Grantor, its successors and assigns, without recourse, covenant or warranty of any kind, express, implied or statutory, the Production Payment insofar and only insofar as the Production Payment covers or applies to the Deleted Leases and the Deleted Wells. Grantor hereby grants, conveys and delivers unto Grantee, its successors and assigns, the Production Payment described in the Conveyance as hereby amended in accordance with the terms and provisions of the Conveyance as hereby amended. 4. Except as expressly amended hereby, the Conveyance shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Conveyance as hereby amended. 5. This instrument is being executed in several counterparts, all of which are identical. Each of such counterparts shall for all purposes be deemed to be an original and all such counterparts shall together constitute but one and the same instrument. WITNESS THE EXECUTION HEREOF, this 29th day of September, 1993, to be effective as of the Effective Date. GRANTOR: WITNESSES: ENRON OIL & GAS COMPANY By: Name: G. E. Uthlaut Title: Sr. Vice President GRANTEE: WITNESSES: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp. General Partner By: Name: Andrew S. Fastow Title: Vice President EXHIBIT "A-1" - Description of Deleted Leases EXHIBIT "A-2" - Description of Deleted Wells EXHIBIT "B-1" - Description of Added Leases EXHIBIT "B-2" - Description of Added Wells EXHIBIT "C" - Recordation Schedule - Conveyance of Production Payment and First Amendment to Conveyance of Production Payment STATE OF TEXAS COUNTY OF HARRIS On this _____ day of _____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ________________________, to me personally known, who, being by me duly sworn, did say that he is the ___________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, and that the instrument was signed in behalf of the corporation by authority of its Board of Directors and that ____________________ acknowledged the instrument to be the free act and deed of the corporation. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary STATE OF TEXAS COUNTY OF HARRIS On this _____ day of ____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ______________________, to me personally known, who, being by me duly sworn, did say that he is the ________________ of Enron Big Piney Corp., General Partner of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, and that the instrument was signed on behalf of said corporation, acting as General Partner of said limited partnership and that _________________________ acknowledged the instrument to be the free act and deed of the limited partnership. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary EXHIBIT A-1 Attached to and made a part of that certain Second Amendment to Conveyance of Production Payment effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED LEASES SUBLETTE COUNTY, WYOMING
ENRON LEASE LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDING 50427-000 W-055275 Township 26 North, Range 112 West, 6th P.M 2/1/59 Not Recorded Section 22: NE/4NE/4, SE/4, S/2NE/4 Section 23: NW/4NW/4, SW/4NW/4,3 E/2NW/4, SW/4 Limited to only the Frontier formation under said lands.
EXHIBIT A-2 Attached to and made a part of that certain Second Amendment to Conveyance of Production Payment effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED WELLS LINCOLN COUNTY, WYOMING
WELL NAME WELL NUMBER LEGAL DESCRIPTION WI BPO NRI BPO WI APO NRI APO Fontenelle 11-36 0912100001 Township 26 North, Range 112 West, 6th P.M. .0170308 .0148326 .0195606 .0161375 Section 36: NW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 12-03 0912200001 Township 25North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 3: SW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 13-11 0912300001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 11: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 13-24 0912400001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195597 .0184859 Section 24: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 13-34 0012400001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195597 .0184859 Section 34: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-01 0912500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 1: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-02 0912600001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 2: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-04 0912800001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: SW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 14-06 0912900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 6: Lot 7 Formation: Consl. Frontier ABCD Fontenelle 14-27 0912700001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 27: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 22-36 0913100001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 36: SE/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 23-07F 0913400001 Township 25 North, Range 111 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 7: NE/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 23-25 0913200001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 25: NE/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 23-33 0913300001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 33: Lot 7 Formation: Consl. Frontier ABCD Fontenelle 31-04 0913500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 31-05 0913600001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 31-06F 0913700001 Township 25 North, Range 111 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 6: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 32-10 0913800001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 10: SW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 33-04 0914100001 Township 25 North, Range 112 West, 6th P.M. .0148326 .0148326 .0195606 .0161375 Section 4: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-12 0128800001 Township 15 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 12: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-13 0913900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 13: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-24 0914000001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 25: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-03 0914000001 Township 15 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 3: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-09 0914500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 9: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-23 0914200001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 23: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-28 0914300001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 28: Lot 9 Formation: Consl. Frontier ABCD Fontenelle 41-09 0914900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 9: NE/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 41-24 0914600001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 24: Lot 1 Formation: Consl. Frontier ABCD Fontenelle 41-26 0914800001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 36: Lot 1 Formation: Consl. Frontier ABCD
EXHIBIT B-1 Attached to and made a part of that certain Second Amendment to Conveyance of Production Payment effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. ADDED LEASES LINCOLN COUNTY, WYOMING
ENRON LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDED 75237-000 ST of WY Township 26 North, Range 112 West, 6th P.M. 2/2/86 Book 236 PR, 86-00117 Section 16: NW/4, NW/4NE/4, S/2NE/4, S1/2 Page 170
EXHIBIT B-2 Attached to and made a part of that certain Second Amendment to Conveyance of Production Payment effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. ADDED WELLS LINCOLN COUNTY, WYOMING
WELL NAME WELL NUMBER LEGAL DESCRIPTION WI BPO NRI BPO WI APO NRI APO Spur Canyon #1 0236940001 Township 26 North, Range 112 West, 100% 75% 100% 75% 6th P.M. Section 16: NE/4NW/4 West Stead Canyon #22-16 0240000001 Township 26 North, Range 112 West, 100% 75% 100% 75% 6th P.M. Section 16: SW/4NE/4 EXHIBIT C Attached to and made a part of that certain Second Amendment to Conveyance of Production Payment effective as of the 1st day of May, 1993 from Enron Oil & Gas Company ("EOG") as Grantor to Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. Document Filing Entity Recording Reference Conveyance of Production Lincoln County Book 317 PR, Page 312 Payment dated September 25, File No. 755518 1992 from EOG to Cactus October 8, 1992 Sublette County Book 89 O&G, Page 512 File No. 238874 October 2, 1992 BLM October 2, 1992 Wyoming State Land November 20, 1992 Board First Amendment to Conveyance Lincoln County Book 330 PR, Page 47 of Production Payment dated File No. 765869 effective April 1, 1993 from June 4, 1993 EOG to Cactus Sublette County Book 92 O&G, Page 341 File No. 241742 May 28, 1993
EX-10.36.D 10 THIRD AMENDMENT TO CONVEYANCE OF PRODUCTION EXHIBIT 10.36(d) THIRD AMENDMENT TO CONVEYANCE OF PRODUCTION PAYMENT Reference for all purposes is hereby made to that certain Conveyance of Production Payment (the "Original Conveyance"), dated September 25, 1992, from ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") to CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), pertaining to certain oil and gas leases, wells and related interests more particularly described therein, which Original Conveyance is recorded as set forth on Attachment A hereto under the caption "Original Conveyance." WHEREAS, the Original Conveyance was amended by that certain First Amendment to Conveyance of Production Payment (the "First Amendment to Conveyance") dated effective as of April 1, 1993 from Grantor to Grantee, recorded as set forth on Attachment A hereto under the caption "First Amendment to Conveyance;" and WHEREAS, the Original Conveyance was further amended by that certain Second Amendment to Conveyance of Production Payment (the "Second Amendment to Conveyance") dated effective as of July 1, 1993 from Grantor to Grantee, recorded as set forth on Attachment A hereto under the caption "Second Amendment to Conveyance;" and WHEREAS, subsequent to the execution, delivery and recordation of the Original Conveyance, pursuant to the terms of the First Amendment to Conveyance and the Second Amendment to Conveyance, certain Leases and Subject Wells as set forth in Parts I and III of Exhibit A to the Original Conveyance have been deleted therefrom and other Leases and Subject Wells have been substituted therefor; and WHEREAS, the Original Conveyance as amended by the First Amendment to Conveyance and the Second Amendment to Conveyance is referred to herein as the "Conveyance;" and WHEREAS, Grantor and Grantee desire to amend the Conveyance as hereinafter set forth effective as of October 1, 1993 (the "Effective Date"): NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Conveyance as follows: 1. Capitalized terms used herein shall have the meanings given to them in Article II of the Conveyance unless otherwise defined herein. 2. Section 1.03 of the Conveyance is hereby amended by deleting same and inserting the following in lieu thereof: Section 1.03 TERMINATION. The Production Payment shall remain in full force and effect until the later of (a) March 31, 1999, or (b) 7:00 a.m. Central Time on the day following the date when any Basis Adjustment Amount outstanding as of March 31, 1999, has been reduced to zero (the "Termination Time"). Upon termination of the Production Payment as above provided, all rights, titles and interests herein conveyed shall automatically terminate and vest in Grantor and upon request by Grantor, Grantee shall execute and deliver such instrument or instruments as may be necessary to evidence the termination of the Production Payment. In the event any individual Subject Interest (or portion thereof, as applicable) should expire (I.E., cease to be in force and effect) before the Termination Time and not be extended, renewed or replaced, the Production Payment no longer shall apply to that particular Subject Interest (or such portion thereof, as applicable), but the Production Payment shall remain in full force and effect and undiminished as to all remaining Subject Interests (and the remainder portion of such Subject Interest, as applicable), and neither the Subject Quantity nor the amount described in the initial sentence of this Section 1.03 shall ever be reduced or diminished by reason of the expiration of a Subject Interest (or the expiration of a Subject Interest as to such portion thereof, as applicable). 3. Schedule 1 and Parts I and III to Exhibit A of the Conveyance are hereby amended by deleting same and substituting Schedule 1 and Parts I and III to Exhibit A attached hereto in lieu thereof. Schedule 1 and Parts I and III to Exhibit A attached hereto are made a part of the Conveyance and supersede Schedule 1 and Parts I and III to Exhibit A attached to the Conveyance. 4. Grantor hereby grants, conveys and delivers unto Grantee, its successors and assigns, the Production Payment described in the Conveyance as hereby amended in accordance with the terms and provisions of the Conveyance as hereby amended. 5. Except as expressly amended hereby, the Conveyance shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Conveyance as hereby amended. -2- EXECUTED in multiple originals this 29th day of October, 1993, but effective as of the Effective Date. GRANTOR: ATTEST: ENRON OIL & GAS COMPANY By: By: Name: D. M. Ulak Name: Andrew N. Hoyle Title: Assistant Secretary Title: Vice President GRANTEE: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp., its General Partner ATTEST: By: By: Name: Elaine Overturf Name: Jere C. Overdyke, Jr. Title: Deputy Corporate Secretary Title: Vice President -3- ATTACHMENTS, EXHIBITS AND SCHEDULES: Attachment A - Recordation Schedule - Original Conveyance; First Amendment to Conveyance; Second Amendment to Conveyance Part I to Exhibit A - Subject Interests Part III to Exhibit A - Subject Wells Schedule 1 - Scheduled Amounts of Production Payment Hydrocarbons -4- STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by _____________________, as _____________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, on behalf of such corporation this _____ day of _____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by ______________________, as __________________ of Enron Big Piney Corp., a Delaware corporation, as General Partner on behalf of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, this _____ day of ____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: -5- ATTACHMENT A Attached to and made a part of that certain Third Amendment to Conveyance of Production Payment DOCUMENT FILING ENTITY RECORDING REFERENCE Original Conveyance County Clerk Book 317 PR, Page Lincoln County 312 File No. 755518 October 8, 1992 County Clerk Book 89 O&G, Page Sublette County 512 File No. 238874 October 2, 1992 Bureau of Land October 2, 1992 Management Wyoming State November 20, 1992 Land Board First Amendment to County Clerk Book 330 PR, Page 47 Conveyance Lincoln County File No. 765869 June 4, 1993 County Clerk Book 92 O&G, Page Sublette County 341 File No. 241742 May 28, 1993 Bureau of Land Management Wyoming State Land Board DOCUMENT FILING ENTITY RECORDING REFERENCE Second Amendment to County Clerk Book 336 PR, Page Conveyance Lincoln County 707 File No. 772470 October 4, 1993 Bureau of Land Management Wyoming State Land Board Part I to Exhibit A (Conveyance)
LEASE LEASE NUMBER LESSOR DATE RECORDING ST COUNTY 50001-00 ENGER K CHRISMAN, ET AL 04/28/1950 BK 2 PG 623 WY SUBLETTE T029N R113W SEC-0010 E2SE4 T029N R113W SEC-0011 W/2SW 50003-00 ENGER K CHRISMAN, ET AL 07/01/1954 BK 10 PG 398 WY SUBLETTE T029N R112W SEC-0018 LOTS 1, 2, E2NW T029N R113W SEC-0011 E2SW, SE T029N R113W SEC-0012 S2SE, NWSW, S2SW T029N R113W SEC-0013 SESW, SENE, SE, NWNW, NWNE, NENE, NENW T029N R113W SEC-0014 N2NE, NENW T029N R113W SEC-0024 N2NE 50005-01 CHAS. P BUDD 11/24/1942 BK 1 PG 371 WY SUBLETTE T029N R113W SEC-0010 N2NE, SWNE 50005-02 THE FRANCES MARGARET GUIO 12/15/1987 BK 81 PG 327 WY SUBLETTE JUNE 16, 1982 FAMILY TRUST T029N R113W SEC-0010 NENE, SENW, SWNE, AS TO ALL DEPTHS BELOW 2,500 FT. 50008-01 PATRICK J QUEALY, ADMIN. 08/15/1957 BK 18 PG 136 WY SUBLETTE T027N R113W SEC-0028 50008-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 140 WY SUBLETTE T027N R113W SEC-0028 SWNE, S2NW 50011-00 USA EV 021983 08/01/1944 BK 31 PG 200 WY SUBLETTE T029N R113W SEC-0014 NWNW 50013-01 SELMER G LARSON 06/11/1957 BK 17 PG 2 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50013-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 144 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50018-00 WILLIAM J. MCGINNIS, ET UX 10/05/1946 BK 2 PG 109 WY SUBLETTE T026N R113W SEC-0023 N2SE (PART OF TR 45) T028N R113W SEC-0024 N2/SW (PART OF TR 45), S2NE, S2NW, (AKA TR 47) 50019-00 USA EV-021741 09/01/1946 BK 88 PG 783 WY SUBLETTE T026N R113W SEC-0004 LOTS 1(39.30), 2(38.74), 3(38.18), 4(37.62), 5(40), 6(40), 7(40), 8(40), 9(40), 10(40), 11(40), 12(40), SE, NWSW T027N R113W SEC-0028 SESW, SWSE T027N R113W SEC-0029 SENE T027N R113W SEC-0032 W2SE, N2NE, SWNE T027N R113W SEC-0033 NWNE, S2NE, SE, NW 50020-00 USA EV-021743 03/01/1947 BK 86 PG 313 WY SUBLETTE T027N R113W SEC-0033 N2SW 50022-01 MATILDA BERTAGNOLLI, ET VIR 10/26/1956 BK 16 PG 150 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50022-02 THOMAS S HARROWER, ET UX 09/06/1957 BK 18 PG 2 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50027-00 USA W-04226 01/01/1951 BK 89 PG 154 WY SUBLETTE T030N R113W SEC-0028 SWNW, N2SW, E2NW, S2SW 50028-00 USA 2-0136178 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113N SEC-0021 S2 50047-00 USA EV-023313-A 02/01/1948 BK314 PG 227 WY LINCOLN T026N R112W SEC-0012 W2E2, LOTS 3,4 T026N R112W SEC-0013 NW, SW 50048-00 USA EV-023313-B 02/01/1948 BK288 PG 640 WY LINCOLN T026N R112W SEC-0012 W2 T026N R112W SEC-0013 LOT 3, W2NE, LOT 4, W2SE 50049-00 ST WY 0-2265 03/02/1944 BK314 PG 49 WY LINCOLN T026N R112W SEC-0016 NENE 50050-00 USA EV-025550 01/01/1948 BK 89 PG 98 WY SUBLETTE T027N R112W SEC-0027 W2 50051-00 USA EV-022929 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0034 NENE, NENE, SE, S2NE, W2 T027N R112W SEC-0035 50052-00 USA EV-026056 12/01/1949 BK 9 PG 128 WY LINCOLN T026N R112W SEC-0011 NE, NENW, N2SW, SE, SESW, SWSW, S2NW T026N R112W SEC-0014 E2, E2NW, SW, W2NW 50053-00 USA EV-022930-A 09/01/1947 BK 8 PG 484 WY LINCOLN T026N R112W SEC-0010 SENE, SENW, SWNE, N2NE, N2NW, SWNW, SW4, N2SE, S2SE T026N R112W SEC-0015 NWNW, NENW, SENW, SWNW, SW, N2N3, S2NE, SE 50054-00 USA EV-022932 09/01/1947 BK 9 OG 66 WY SUBLETTE T026N R112W SEC-0002 NESE, NWSE, SENE, SW, SWNE, S2NW, S2SE, LOTS 1, 2, 3, 4 T026N R112W SEC-0003 S2, S2N2, LOTS 1, 2, 3, 4 T026N R112W SEC-0004 SE T026N R112W SEC-0009 N2, N2SE, SESE, SW, SWSE T026N R112W SEC-0011 NWNW 50088-00 USA W-92217 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0017 N2NW, SESW T028N R112W SEC-0018 NE, LOTS 1, 2, 3, E2NW, NESW T028N R112W SEC-0019 SWNE, E2SW, W2SE, E2NE, E2SE T028N R112W SEC-0020 W2SW. MW. E2SW 50094-00 USA EV-022261 09/01/1946 BK 90 PG 107 WY SUBLETTE T026N R113W SEC-0019 SE, SWNE, SENE, LOT 5, NWNE T028N R113W SEC-0031 E2NE T028N R113W SEC-0032 LOT 1, N2NW, SWNW 50101-00 USA EV-025991 04/01/1952 BK 89 PG 82 WY SUBLETTE T029N R113W SEC-0034 ALL 50113-00 MYRON EDGAR MILLS ET UX 05/20/1953 BK 5 PG 107 WY SUBLETTE T028N R113W SEC-0022 SESE T028N R113W SEC-0023 E/2SW, SWSW, SAID LANDS BEING NOW RESURVEYED INTO AND AS TRACT 44 50131-00 USA W-48904 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 LOT 1 (NENE - 39.78 AC), SENE T028N R113W SEC-0032 W2N2 T028N R113W SEC-0032 LOT 6 (SESE- 47.69) E2NE, NESE T028N R113W SEC-0033 SWNW 50133-00 USA EV-010270-B 10/16/1939 BK 89 PS 112 WY SUBLETTE T027N R113W SEC-0021 N2N2 50134-00 USA W-0256493 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 3, 4, NE, N2SE T028N R113W SEC-0034 LOT 1, W2NW, NWSW 50135-00 USA W-0256 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0009 W2NE 50136-00 USA EV-026191 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 SESW. SWSE 50137-00 USA W-048780 07/01/1947 BK 89 PG 89 WY SUBLETTE T027N R113W SEC-0004 LOTS 2, 3, SWNE 50138-00 USA EV-022209 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 1, 2 N2SW 50139-00 USA W-9653 03/10/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 LOT 4, S2NW, N2SW, NWSE 50140-00 ST WY 0-847 09/16/1936 BK PG WY SUBLETTE T027N R113W SEC-0016 ALL 50141-00 USA EV-09561-A 06/20/1932 BK 89 PG 65 WY SUBLETTE T027N R113W SEC-0017 NE, E2NW, SE, NESW T027N R113W SEC-0020 NENE, NWNE, S2NE 50142-00 USA EV-021978 01/01/1940 BK 2 PG 173 WY SUBLETTE T027N R113W SEC-0004 SWSW T027N R113W SEC-0009 NW, E2SW, W2SE 50143-00 USA EV-07555 01/01/1940 BK 89 PG 70 WY SUBLETTE T027N R113W SEC-00094 W2SW 50144-00 USA EV-07671-A 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 SE 50145-00 USA EV-07671-B 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 N2, N2SW, S2SW 50147-00 USA W-48907 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 N2SE, SWNE, LOTS 2, 3, 4, S2NW, N2SW, S2S2 T028N R113W SEC-0033 SENW 50149-00 USA W-0125385 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0019 LOTS 3, 4 50150-00 USA W-0125387 01/01/1950 BK 85 PG 605 WY SUBLETTE T028N R112W SEC-0030 LOT 1 50151-00 USA W-0125388 06/01/1948 BK 85 PG 621 WY SUBLETTE T028N R113W SEC-0023 NENW, NWNE, LOTS 1, 2, 3, NENE T028N R113W SEC-0024 LOTS 3 (48 AC) LOT 4 (48.77 AC) 50152-00 USA EV-022756 09/01/1946 BK 89 PG 17 WY SUBLETTE T028N R113W SEC-0014 S2NW, SW, N2NW 50153-00 USA EV-023554 01/01/1948 BK 89 PG 19 WY SUBLETTE T028N R113W SEC-0026 SESW, S2SE, LOT 1, SENW, NESW, N2SE, NE 50154-00 USA EV-024756 06/01/1948 BK 67 PG 70 WY SUBLETTE T028N R113W SEC-0023 LOTS 5, 6, 7 T028N R113W SEC-0024 LOTS 5, 6, 7, 7, 8, TRACT 46 A&B T028N R113W SEC-0025 LOTS 1, 2, 3, 4, W2E2, E2W2, SWSW, W2N2, NWSW 50155-00 USA EV-024792 07/01/1948 BK 85 PG 614 WY SUBLETTE T028N R113W SEC-0034 LOT 2 50156-00 USA W-02985 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0035 LTS 1, 2, 3, 4, 5, 6, 7, W2NE, N2NW, SWNW, N2SW, NWSE 50157-00 USA W-02985-A 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0034 SENW 50158-00 USA W-046892 02/01/1957 BK 85 PG 582 WY SUBLETTE T028N R113W SEC-0034 E2N2, SWNE, N2SE, LOTS 3 & 4 50159-00 USA W-05283 02/01/1951 BK 31 PG 229 WY SUBLETTE T028N R113W SEC-0004 LOTS 5, 6, S2N2, N2SE, SESE, SWSE 50160-00 USA W-08056 09/01/1951 BK 32 PG 63 WY SUBLETTE T028N R113W SEC-0034 E2NW, NESE, NWNE 50161-00 USA W-10675 09/01/1950 BK 31 PG 274 WY SUBLETTE T029N R113W SEC-0035 W2SW, SESW, NESW 50162-00 USA W-10677 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 NESE, SENW, SESE, S2NE T029N R113W SEC-0027 NESE, SENW, SESE, S2NE 50163-00 USA W-10679 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R113W SEC-0003 S2/SW 50164-00 STATE OF WYOMING 0-11142 05/16/1951 BK 19 PG 243 WY SUBLETTE T028N R113W SEC-0005 E2SW, SE, NW (PART OF RESURVEY TRACT 54) 50165-00 ST WY 020810 06/16/1956 BK 85 PG 669 WY SUBLETTE T028N R113W SEC-0036 W2SW 50166-00 USA W-06861 07/01/1951 BK 85 PG 40 WY SUBLETTE T028N R113W SEC-0015 SENE, N2NE 50167-00 USA W-014074 06/01/1952 BK 89 PG 96 WY SUBLETTE T029N R113W SEC-0035 N2NW, SENW, SWNW 50169-00 USA W-0125384 05/01/1948 BK 31 PG 242 WY SUBLETTE T028N R113W SEC-0011 E2 T028N R113W SEC-0013 SW T028N R113W SEC-0014 SWNE, W2SE, N2NE, SENE, E2SE 50170-00 USA W-10681 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 E2NE, NESE, NWSE, S2SE, W2NE T029N R113W SEC-0026 NWNW T029N R113W SEC-0027 N2NE 50171-00 USA W-10682 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 NW, N2SW, S2SW T029N R113W SEC-0024 E2SE, NENW, NWNW, NWSE, SENW, SW, SWMW, SWSE, S2NE T029N R113W SEC-0025 NENW T029N R113W SEC-0027 NENW 50172-00 CHARLES P NOBLE ET UX 02/03/1954 BK 7 PG 360 WY SUBLETTE T029N R113W SEC-0011 E2NW, NE T029N R113W SEC-0012 W2NW 50173-00 USA EV-024549-A 07/01/1951 BK 22 PG 137 WY LINCOLN T026N R112W SEC-0005 THAT PORTION OF THE GREEN RIVER RIPARIAN TO LOTS 4, 5, 6, 7, 10, 11 AND 13 T026N R112W SEC-0008 THAT PORTION OF THE GREEN REIVER RIPARIAN TO LOTS 1, 2, 4, 5, 6, 7 AND 11 50174-00 USA W-20951 09/01/1947 BK9PR PG 66 WY LINCOLN T026N R112W SEC-0004 LOTS 1, 2, 3, 4, S2N2, SW4 50175-00 USA EV-022929-A 09/01/1952 BK9PR PG 206 WY SUBLETTE T027N R112W SEC-0033 NW4 50176-00 USA W-022931 11/01/1947 BK24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOTS 4 (17.01), 7 (7.50), 10 (25.29), 11 (42.73), 13 (23.59) AND SWSE T026N R112W SEC-0008 LOT 1 (12.18), 2, (19.72), 4 (32.67), 5 (20.41), 6 (18.10), AND W2NE LOT 7 (43.63), 11 (30.54) BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0029 LOTS 2 (35.76), 3 (16.18), 4 (45.23), 5 (6.90), 8 (6.23), 9 (37.63), 10 (1.67), 11 (22.05), 12 (23.76) 50177-00 USA EV-022931-A 11/01/1947 BK 24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOT 1 (36.87), SENE, E2SE T026N R112W SEC-0008 E2NE, E2SE BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0028 ALL T027N R112W SEC-0029 E2SE T027N R112W SEC-0032 SENE, E2SE, NENE 50178-00 USA EV-022935 10/01/1947 BK 43 PG 242 WY LINCOLN T026N R112W SEC-0005 LOTS 5 AND 6 50180-00 USA EV-023229-A 07/01/1947 BK 89 PG 52 WY SUBLETTE T027N R112W SEC-0021 LOTS 9, 10, 11, SWSW 50181-00 USA W-20950 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0033 SE, NE4 T026N R112W SEC-0008 E2NE, E2SE 50182-00 USA W-039163 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0029 THAT PORTION OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 3, 4, 5, 8, 9, 10, 11, 12 50183-01 KENNETH BARLETT, GUARDIAN 10/29/1958 BK 22 PG 349 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-02 ATHOL L STOTTS, ET UX 01/23/1956 BK 15 PG 79 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-03 MARY MAXINE DELANEY, ET AL 01/23/1956 BK 15 PG 231 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50183-04 FLORENCE VICKREY, ET AL 01/23/1956 BK 15 PG 295 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50184-01 SELMER G LARSON, RECEIVER 06/21/1956 BK 18 PG 216 WY LINCOLN T026N R112W SEC-0008 LOTS 8 (16.37), 9 (28.05), 10 (41.40), SWSW 50184-02 WILLIAM J MCGINNIS 06/21/1956 BK 18 PG 214 WY LINCOLN T026N R112W SEC-0008 LOTS 8, 9, 10, SW4SW4, BED OF GREEN RIVER RIPARIAN TO LOTS 8, 9, & 10 50185-00 BENEFICIAL OIL CO. 09/16/1959 BK 24 PG 537 WY SUBLETTE T027N R112W SEC-0017 N2NE, SENE, NENW T027N R112W SEC-0020 LOTS 1, 2 & 5, NENE, NWSE T027N R112W SEC-0021 LOTS 2 (16.93), 3 (39.25), 4 (11.04), 5 (15.73), 6 (20.24), NWNW 50186-00 M F WHELAN LIVESTOCK COMPANY 01/25/1954 BK 9 PG 63 WY SUBLETTE T027N R112W SEC-0029 INSOFAR AS LSE COVERS: LOT 7 (NW/4SE/4) T027N R112W SEC-0032 INSOFAR AS LSE COVERS: NWNE, INCLUDING RIPARIAN RIGHTS IN THE GREEN RIVER 50187-00 USA W-06206 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 E2 T030N R113W SEC-0015 N2NW, NWNE, S2N2, NENE, N2S2, SESW, S2SE 50198-00 USA W-10678 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 S/2NE, N/2SE, SESE 50213-00 USA W-23002 03/01/1970 BK 58 PG 661 WY SUBLETTE T030N R113W SEC-0008 SESW, NESW, SWSW T030N R113W SEC-0017 NW, SW 50269-00 USA W-0322521 03/01/1966 BK 294 PG 638 WY LINCOLN T026N R113W SEC-0009 SESW 50270-00 ST WY 63-11625 08/02/1963 BK 204 PG 257 WY LINCOLN T026N R113W SEC-0016 ALL 50272-00 USA W-09156B 06/01/1948 BK 17 PG 283 WY LINCOLN T026N R113W SEC-0008 NE, N2SE, SESE, E2NW T026N R113W SEC-0009 W2W2M E2NW, NESW 50274-00 USA W-020123-A 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0004 SWSW T027N R112W SEC-0005 SESE, LOT 4, S2NW, SW, N2SE, W2SE T027N R112W SEC-0009 SWSW T027N R112W SEC-0017 SE, SWNE T027N R112W SEC-0029 W2NE 50275-00 USA W-025407A 05/01/1954 BK 34 PG 635 WY SUBLETTE T027N R112W SEC-0031 LOTS 1, 2, 5, 6, 7, 8, 11, 12, E2NWNE, W2NWNE T030N R113W SEC-0017 NW, SW 50276-00 USA W-020123 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0006 ALL T027N R112W SEC-0008 W2NW, SENW, SW T027N R112W SEC-0020 LOT 6, NW, N2SW, SWSW 50277-00 USA EV-023313 02/01/1948 BK 286 PG 640 WY LINCOLN T026N R112W SEC-0006 SWNE 50278-00 USA EV-023313 02/01/1948 BK K286 PG 640 WY LINCOLN T026N R112W SEC-0006 SESW, NESW, SWSW 50279-00 USA W-024793 02/01/1954 BK 30 PG 138 WY LINCOLN T026N R113W SEC-0014 SENW, SW T026N R113W SEC-0022 NENE, SENE, SENW, SWNE T026N R113W SEC-0023 N2NW, LOTS 1, 2, 3, 4 50280-00 USA W-022407 05/01/1954 BK 150 PG 334 WY SUBLETTE T027N R112W SEC-0006 LOTS 3, 4, 7, 8, NENE, W2NE, NWSE, N2SWSE, SESWSE, SWSWSE 50281-00 USA W-025410 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0030 LOTS 1, 2, 5, 6, E2W2 BK 30 PG 490 WY LINCOLN T027N R112W SEC-0002 LOT 1 50282-00 USA W-025410-A 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0031 LOTS 3, 4, 7, 9, NWNENW, W2SE, S2SWNE, NESWNE LOT 10, E2NENW, SWNENW, SENW, NWSWNE, E2SW 50283-00 USA EV-025440 03/01/1950 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0007 NE, W2SE, E2SE T027N R112W SEC-0018 S2NE, SE, N2NE 50284-00 USA EV-025440-A 03/01/1955 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0019 E2 50285-00 USA W-033951 07/01/1955 BK 296 PG 257 WY SUBLETTE T026N R113W SEC-0010 S2NE 50286-00 USA W-036054 04/01/1956 BK 21 PG 292 WY SUBLETTE T027N R113W SEC-0027 NWNE 50287-00 USA W-038682 09/01/1956 BK 288 PG 52 WY LINCOLN T026N R113W SEC-0002 LOTS 2, 3, 5, 6, 12 BK 70 PG 151 WY SUBLETTE T027N R113W SEC-0035 W/2 50288-00 USA W-03682-A 09/01/1956 BK 88 PG 52 WY LINCOLN T026N R113W SEC-0014 LOTS 3, 4 50290-00 USA W-047412 09/01/1958 BK 88 PG 123 WY SUBLETTE T027N R112W SEC-0009 LOT 1 50291-00 USA W-0499597412 06/01/1957 BK 23 PG 512 WY LINCOLN T026N R112W SEC-0006 THAT PORTION OF THE BED OF GREEN RIVER RIPARIAN TO LOT 7 50292-00 USA W-050961 09/01/1957 BK 24 PG 335 WY LINCOLN TO26N R112W SEC-0006 LANDS COVERING ALL OF THE BED OF THE GREEN RIVER LYING IN LOT 6 BETWEEN THE MEAN HIGH WATER MARKS THEREOF, EXCEPTING THAT PORTION OF THE SAID RIVER BED WHICH LIES RIPARIAN TO LOT 7 OF SEC 6. SAID LANDS BEING ONLY THAT PORTION OF THE BED OF THE GREEN RIVER APPURTENANT TO LOT 6. 50293-00 USA W-052064 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0007 LOT 5 T026N R112W SEC-0018 LOT 1, 2, 3, PAGE 12 50294-00 USA W-052065 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0006 LOT 1, 2, 3, 4, 5, 6, 7, 9 50295-00 USA W-05751 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0007 LOTS 1, 2, 3, 4, E2W2 T027N R112W SEC-0018 LOT 1, 2, E2NW, LOTS 3, 4, E2SW 50296-00 USA W-05751-A 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0019 LOT 1, 2, 3, 4, E2W2 50297-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0030 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 4, 7, 8 50298-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0031 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, 5, 6, 7, 8 11, 12 50299-00 USA W-059585 07/01/1947 BK 85 PG 49 WY SUBLETTE T027N R112W SEC-0009 LOTS 2 (6.59), 3 (10.11) T027N R112W SEC-0020 LOTS 3, (4.94), 4 (20.40) 50300-00 USA W-066369 07/01/1988 BK305 PG 26 WY LINCOLN T026N R113W SEC-0015 S/2 50301-00 USA W-066370 10/11/1958 BK305 PG 30 WY LINCOLN T026N R112W SEC-0022 N2NW, NWNE, SWNW, NWSW 50302-00 USA EV-07798-E 09/01/1954 BK 30 PG 22 WY LINCOLN T026N R113W SEC-0002 LOT 4 (41.5) T026N R113W SEC-0010 SE T026N R113W SEC-0011 N2NW, SENW, SW, W2NE, W2SE, LOTS 1, 2, 3, 4 T026N R113W SEC-0014 N2NW, SWNW, W2NE, W2SE, LOTS 1, 2 T026N R113W SEC-0015 N2N2 50303-00 USA EV-08051-B 04/01/1958 BK 86 PG 278 WY SUBLETTE T027N R113W SEC-0027 E2NE, E2SWNE 50304-00 ST WY 0-11135 05/16/1951 BK 22 PG 430 WY LINCOLN T026N R113W SEC-0013 ALL (RES PT LOT 37) 50305-00 ST WY 0-1137 05/16/1951 BK 22 PG 433 WY LINCOLN T026N R113W SEC-0024 S2N2 (RES LOT 39) 50306-00 ST WY 0-11141E 05/16/1951 BK 21 PG 272 WY SUBLETTE T027N R113W SEC-0036 ALL 50307-00 ANDERSON L MCGINNIS, ET UX 12/26/1956 BK 16 PG 336 WY SUBLETTE T027N R112W SEC-0003 PARTS OF LOTS 3 & 4 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT ON THE EAST LINE OF SAID LOT 3, 325' SOUTH OF THE OLD PARTITION FENCE, THENCE ALONG SAID FENCE 89 DEGREES WEST TO THE WEST BOUNDARY OF SAID LOT 4, THENCE SOUTH TO THE SW CORNER OF SAID LOT 4, THENCE EAST TO THE SE CORNER OF SAID LOT 3, THENCE NORTH TO THE PLACE OF BEGINNING. THAT PART OF LOT 5 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT 1635' SOUTH OF THE QUARTER SECTION CORNER ON THE NORTH LINE OF SAID SECTION AND RUNNING THENCE EAST ALONG THE MCGINNIS MICKELSON PARTITION FENCE TO THE GREEN RIVER, THENCE IN A SOUTHEASTERLY DIRECTION ALONG GREEN RIVER TO THE EAST AND WEST QUARTER SECTION LINE IN SAID SECTION 3, THENCE WESTERLY ALONG SAID EAST AND WEST QUARTER SECTION LINE TO THE CENTER OF SAID SECTION 3, THENCE NORTH TO THE PLACE OF BEGINNING. E2SW, NWSW, SWSW, S2NW, LOTS 8 & 9 T027N R112W SEC-0004 SE, SESW, S2NE, LOT 1 T027N R112W SEC-0008 E2NE T027N R112W SEC-0009 NW, N2NE, N2SW, SESW, SWNE, S2SE, LOTS 1, 4, 5 T027N R1112W SEC-0010 LOTS 2, 3, 7 50308-00 ST WY 0-11134 05/16/1951 BK 22 PG 439 WY LINCOLN T026N R113W SEC-0012 ALL 50309-01 SELMER G LARSON 01/08/1957 BK 20 PG 434 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, W2, SE T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, NESW, NE4, N2SE4 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW 50309-02 NEWT SIMS LARSON 12/15/1956 BK 20 PG 234 WY LINCOLN T026N R112W SEC-0017 S2S2 T026N R112W SEC-0018 PART SESE E OF HWY 189 T026N R112W SEC-0019 PART E2NE, NESE E HWY 189 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW, LOTS 2, 3, 6 50309-03 WILLIAM J MCGINNIS ET UX 11/13/1956 BK 19 PG 394 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, N2SE, NW, N2SW T026N R112W SEC-0018 W2NE, E2NW, NESW, SESW, LOT 4, SWSE, NE4, N2SE T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, W2NE, NESW, NWSE, ALSO ALL THAT PART OF THE SE4SE4 SEC 18; E2NE4, NE4SE4, SEC. 19 LYING WEST OF STATE HWY 287, CENTER LOCATION OF SAID HWY BEING LOCATED IN SAID SE4SE4, SECTION 18 AND E2NE4, NE4SE4, SEC. 19 AS FOLLOWS: 958 FEET WEST OF NE CORNER OF SE4SE5, SEC. 18; 701 FEET WEST OF NE CORNER, SEC. 19; 554 FEET WEST OF EAST SECTION LINE ALONG THE HALF SECTION LINE OF SEC. 19; AND 177 FEET WEST OF SE CORNER OF SEC. 19, CONTAINING 1,375.10 ACRES, MORE OR LESS. 50310-00 ST WY 0-11216B 05/16/1951 BK 3 PG 468 WY SUBLETTE T027N R112W SEC-0016 W2 50311-00 USA W-048781 06/01/1956 BK 24 PG 339 WY SUBLETTE T0276N R113W SEC-0035 E/2 50312-00 ST WY 0-11136 05/16/1951 BK 22 PG 436 WY LINCOLN T026N R112W SEC-0024 N2N2 (RES LOT 38) NWSW (RES LOT 40) 50318-00 GEORGE E YEAMAN ET UX 11/29/1956 BK 20 PG 248 WY LINCOLN T026N R112W SEC-0007 W2NE, NENE, LOT 3 T026N R112W SEC-0008 LOT 3, EXCEPT HWY TRACT 50319-00 WINSTON H ALLEMAN ET UX 02/26/1959 BK 32 PG 445 WY LINCOLN T026N R112W SEC-0005 LOT 12 T026N R112W SEC-0006 THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLAT NO. 1 FOR SW4SE4 AND NW4SE4 SECTION 6-26-112 LINCOLN COUNT LOT 2: ALL LINCOLN COUNTY LOT 3: ALL LINCOLN COUNTY LOT 8: ALL, EXCEPT FOR THE FOLLOWING DESCRIBED PARCELS: BEGINNING AT THE SOUTH WEST CORNER OF THE SOUTH WEST QUARTER OF THE SOUTH EAST QUARTER (SW4SE4) OF SECTION SIX THENCE EAST ON THE SECTION LINE BETWEEN SAID SECTIONS SIX (6) AND SEVEN(7), TOWNSHIP TWENTY-SIX NORTH, RANGE ONE HUNDRED TWELVE WEST OF THE 6TH P.M. IN WYOMING, A DISTANCE OF 1043.35 FEET; THENCE NORTH A DISTANCE OF 835 FEET; THENCE WEST A DISTANCE OF 1043.35 FEET; THENCE SOUTH ON THE MID-SECTION LINE OF SAID SECTION SIX A DISTANCE OF 835 FEET TO THE POINT OF BEGINNING. TWO AND NINETY SEVEN HUNDREDTHS ACRES MORE OR LESS, STARTING FROM A POINT 1043.35 FEET EAST AND 835 FEET NORTH OF THE SOUTH WEST CORNER OF LINCOLN COUNTY, LOT NUMBER 8 AS SHOWN UPON LINCOLN COUNTY METES AND BOUNDS MAP NUMBER ONE, SECTION 6, TOWNSHIP 26 NORTH, RANGE 112 WEST; THENCE IN A NORTHERLY DIRECTION PARALLEL TO THE WEST BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 TO THE NORTH BOUNDARY OF SAID LOT 8; THENCE WEST ALONG THE NORTH BOUNDARY LINE OF SAID LOT NUMBER 8 TO THE CORNER THAT IS 566.31 FEET FROM ITS WESTERN BOUNDARY, THENCE IN A SOUTHERLY DIRECTION PARALLEL TO THE WESTERN BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 FOR A DISTANCE OF 271.35 FEE; THENCE IN AN EASTERLY DIRECTION TO THE POINT OF BEGINNING. LINCOLN COUNTY LOT 21: ALL LA BARGE TOWN LOTS 5-12; INCLUSIVE IN BLOCK 1 51% OF LOTS 1 & 2, AND ALL OF LOTS 5-20, INCLUSIVE IN BLOCKS 3 OF THE SECOND ADDITION AND LOT 23, BLOCK 1 OF THE ORIGINAL TOWNSITE. THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLATE NO. 2, FOR LOTS 8 & 11, SECTION 6-26-112 LINCOLN COUNTY LOT 19: ALL LINCOLN COUNTY LOT 20: ALL 50320-01 CYRIL HOUSLEY ET UX 11/14/1956 BK 19 PG 398 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, NWSE, SENW, NESW 50320-02 AUGUSTA B MARX 11/19/1956 BK 19 PG 475 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, SENW, NWSE, NESW 50322-00 ST WY 0-22646T UX 11/16/1958 BK 35 PG 543 WY LINCOLN T026N R112W SEC-0001 ALL OF ORIGINAL SECTION 1 50324-00 JOHN E MARX ET UX 11/01/1956 BK 19 PG 353 WY LINCOLN T026N R112W SEC-0006 E2SW, LOT 10 T026N R112W SEC-0007 LOT 1, NENW 50325-00 USA W-033913 11/01/1956 BK 22 PG 419 WY SUBLETTE T028N R112W SEC-0033 W2NW, NWSE, NENE, S2NE, E2NW, NWNE, SWSE, E2SE 50329-01 WY STATE HWY COMMISSION 08/22/1958 BK 32 PG 379 WY LINCOLN T026N R112W SEC-0006 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 1: E2SE PARCEL 2: LOT 11, SWSE T026N R112W SEC-0007 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 3: E2NE PARCEL 4: E2SE PARCEL 5: E2SE, SWSE PARCEL 6: NWSE PARCEL 7: LOT 3, NENE, W2NE PARCEL 8: W2NE PARCEL 9: NENW, LOT 1 PARCEL 10: PARCEL OF LAND INCLUDED WITHIN THE RIGHT OF WAY OF THE STAT HIGHWAY PROJECT L. N. -10 & F.A. PROJECT 158A, KNOWN AS THE KEMMERER-MARBLETON ROAD, SAID RIGHT-OF- WAY BEING 80' WIDE AND LYING 40' ON EITHER SIDE AND BEING EQUIDISTANT FROM A CERTAIN CENTER LINE DESCRIBED BY COURSES AND DISTANCES AS FOLLOWS: BEGINNING AT A POINT DESIGNATED IN THE FIELD NOTES OF THE SURVEY OF THE ABOVE MENTIONED HIGHWAY AS STATION 1276 40.0, SAID POINT BEING ON THE SOUTH BOUNDARY LINE OF NESE OF SECTION 19-26N-112W, 6TH P.M.; AND N 17 DEGREE 11' W A DISTANCE OF 1129.9' FROM POINT WHICH IS N 31 DEGREE 48' W A DISTANCE OF 337.3' FROM A POINT WHICH IS EAST A DISTANCE OF 250' FROM THE SE CORNER OF SECTION 19, AFORESAID; THENCE N 17 DEGREE 11' W A DISTANCE OF 1076.2' TO A POINT OF AN 8 DEGREE 00' CURVE TO THE RIGHT, THE RADIUS OF WHICH IS 716.2', THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 16 DEGREE 00', A DISTANCE OF 200'; THENCE N 1 DEGREE 11; W A DISTANCE OF 2142.3'; THENCE N 1 DEGREE 21' E 145.2' TO POINT OF A 10 DEGREE 00' CURVE TO THE LEFT, THE RADIUS OF WHICH IS 573'; ALONG SAID CURVE THROUGH AN ANGLE OF 21 DEGREE 40' A DISTANCE OF 216.7; THENCE N 20 DEGREE 19' W A DISTANCE OF 484.3" TO A POINT OF A 6 DEGREE 00' CURE TO THE RIGHT, THE RADIUS OF WHICH IS 954.9'; THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 11 DEGREE 23' A DISTANCE OF 189.7; THENCE N 8 DEGREE 56' W A DISTANCE OF 2582.7' TO THE POINT OF A 5 DEGREE 00' CURVE TO THE RIGHT, THE RADIUS OF WHICH IS 1145.9'; THENCE ALONG SAID CURVE, THROUGH AN ANGLE OF 9 DEGREE 11' A DISTANCE OF 183.7'; THENCE N 0 DEGREE 15' E A DISTANCE OF 4889.2, THE END, WHICH IS STATION 1397 50 OF SAID SURVEY, WHICH POINT IS ON THE E & W CENTER LINE OF SECTION 7, 26N-112W OF THE 6TH P.M. T026N R112W SEC-0018 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: E2SE, E2NE PARCEL 5: NE T026N R112W SEC-0019 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NESE, E2NE PARCEL 5: NENE PARCEL 10: SEE METES AND BOUNDS DESCRIBED IN SECTION 7 T026N R112W SEC-0020 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NWSW 50343-00 USA W 05749 05/01/1951 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0010 LOT 1, NENE, S2NE T027N R112W SEC-0011 NE T027N R112W SEC-0012 S2N2, SE T027N R112W SEC-0013 E2 50344-00 USA W-066702 07/01/1947 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 LOT 4 AND 5 50346-00 USA W-278782 04/01/1971 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0001 SE T027N R112W SEC-0012 N2NE 50347-00 USA EV-023053 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2NE 50348-00 USA EV-023053-A 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2SE 50349-00 USA EV-023057 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0010 SE T027N R112W SEC-0015 W2NE 50350-00 USA EV-023057-A 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0015 W2SE 50351-00 USA EV-023066 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0010 E2SW, LOTS 6, 8 T027N R112W SEC-0015 E2NW, SWNW, LOT 1 50352-00 USA EV-023066-A 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0015 SW 50353-00 USA W-053031 09/01/1957 BK 87 PG 702 WY SUBLETTE T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER RIPARIAN TO LOT 2 MORE FULLY DESC. BY METES & BOUNDS IN LSE. 50354-00 USA W-066701 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 4, 5, 6, 8 T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOT 1 ALL ACRES SHOWN IN SEC 10 50355-00 USA W-07828 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R112W SEC-0003 LOTS 7 (NENW), 8 (NWNW), S2NW, N2SW 50362-00 USA W-01332 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 SESE, SWSE, N2SE, S2NE, SENW 50365-00 USA EV-013494 12/31/1938 BK 31 PG 333 WY SUBLETTE T029N R113W SEC-0014 SW, W2SE, S2NW, SWNE T029N R113W SEC-0023 E2 50380-00 USA W-60577 11/01/1977 BK 73 PG 208 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1, 2, 3, 4, E2, E2W2 T028N R111W SEC-0031 NE, E2SE T027N R111W SEC-0032 W2 50384-00 USA W-62791 05/01/1978 BK 65 PG 556 WY SUBLETTE T028N R111W SEC-0025 E2 LOT 1 (20.64 AC) LOT 3 (41.1 AC) 40.82 AC) LOT 6 (30.22 AC) LOT 7 (40.54 AC), SESWNE, SENESW, SESW, W2SE T028N R111W SEC-0031 LOTS 1 (NWNW), 2(SWNW), E2NW, W/2SE LOTS 3 (NWSW), 4 (SWSW), E2SW 50431-00 USA EV-022769-A 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0001 LOTS 3, 4, S2NW, SW T029N R113W SEC-0002 LOTS 1, 2, 3, 4, S2NE SENW, S2 50432-00 USA EV-0177710-B 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0028 E2 T030N R113W SEC-0034 N2SW, SE, SESW 50434-00 USA EV-017710-A 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0034 SWSW 50435-00 USA EV-022769 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0003 LOTS 1 32.83), 2 (32.18) 3 (31.53), 4 (30.88) S/2N/2, SW, S/2SE, NWSE T029N R113W SEC-0004 LOTS 1 (31.11), 2(32.20)M 3 (33.30), S/2NE, SENW, NESW, N/2SE T030N R113W SEC-0033 E/2, E/2W/2 55787-01 KATHLEEN ANN MILLER 08/31/1986 BK 77 PG 548 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-02 ROBERT M MILLER JR ET UX 08/13/1986 BK 77 PG 554 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-03 MATTHEW DANIEL MILLER 08/13/1986 BK 77 PG 550 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-04 PATRICIA M ROBERTS ET VIR 08/13/1986 BK 77 PG 552 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-05 PRISCILLA KYSAR ET VIR 08/13/1986 BK 77 PG 546 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-06 ALBERT E SCHWABACHER ET AL 04/13/1988 BK 81 PG 655 WY SUBLETTE T029N R113W SEC-0011 W2NW 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW T029N R113W SEC-0003 NESE 57790-00 USA W-01763 03/01/1986 BK274 PG 531 WY LINCOLN T029N R112W SEC-0013 LOTS 1 & 2 57808-00 USA EV-026240 11/01/1950 BK305 PG 95 WY LINCOLN T026N R113W SEC-0023 NWNE 57809-00 USA W-059091 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, & 3 T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 3 & 4 57810-00 USA W-025765 06/01/1954 BK305 PG 89 WY LINCOLN T0276 R112W SEC-0002 LOTS 7, 8, 9, 10, & 11 57821-00 JOSEPH W KRALL 03/23/1989 BK 82 PG 551 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/SW 57821-02 SUSAN K DONALDSON ET VIR 03/23/1989 BK 82 PG 643 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-03 SALLY ORR, ET VIR 03/23/1989 BK 82 PG 641 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-04 JUDY BETKA, ET VIR 03/23/1989 BK 82 PG 645 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-05 NANCY JO T KNADLER, ET VIR 03/22/1989 BK 82 PG 549 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-06 TED E MILLER 03/29/1989 BK 82 PG 635 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-07 FRANK T MILLER 03/29/1989 BK 82 PG 637 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-08 MARILYN JAMES, ET VIR 03/31/1989 BK 82 PG 639 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57964-00 USA WYW-034923 10/01/1950 BK314 PG 254 WY LINCOLN T0267N R113W SEC-0008 SWSE 75007-00 USA WY-088276 07/01/1961 BK 50 PG 61 WY LINCOLN T026N R113W SEC-0011 SWNW 75012-00 USA EV-021976 04/01/1949 BK 18 PG 130 WY LINCOLN T026N R113W SEC-0005 LOT 3, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 6, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75013-00 USA EV-025792 09/01/1946 BK314 PG 218 WY LINCOLN T026N R113W SEC-0005 LOT 1, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 7, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 8, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75021-00 USA W-104985 08/01/1987 BK263 PG 159 WY LINCOLN T026N R111N SEC-0008 N2NW, SENW 75022-00 USA WYW-102101 11/01/1986 BK263 PG 163 WY LINCOLN T026N R111N SEC-0008 N2NW, SWNW, SWSW T026N R111N SEC-0022 SWNW, S2 T026N R111N SEC-0028 NENE 75047-00 USA WYW-11667 12/01/1988 BK314 PG 241 WY LINCOLN T026N R114W SEC-0011 NE, S2 T025N R114W SEC-0012 LOTS 1-12, W/2 T025N R114W SEC-0013 LOTS 1-12, W/2 75052-00 CARL TAYLOR, ET UX 04/22/1959 BK 34 PG 187 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS: BLOCK 1: LOTS 3 & 19 = .13774 AC BLOCK 3: LOTS 1, 2, 3, 4, 8, 9, 10, 11 AND 12 = .61983 AC BLOCK 12: LOTS 1,2,3,4,5,6,7, AND 8 -.55096 ACRES 75054-00 C J PAYNE, ET UX 03/07/1959 BK 34 PG 183 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 27,28,29 BLOCK 5: LOTS 15,16 BLOCK 7: LOT 15 CONTAINING .41322 ACRES 75055-00 JAMES A DEGRAW, ET UX 03/07/1959 BK 34 PG 181 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOTS 6,7,8,9,10 BLOCK 11: LOT 1 CONTAINING .41322 ACRES 75056-00 CECIL J STUDT, ET UX 03/07/1959 BK 34 PG 179 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK A: RIVER VIEW ADDITION LOT 3 BLOCK C: RIVER VIEW ADDITION LOTS 1,2,3,4,5,6,7,8 BLOCK 5: LOTS 1,2,3,4,5,6,7,8,17,18,19,20,21,22,23 CONTAINING 1.65309 ACRES 75057-00 CYRIL HOUSLEY, ET UX 03/07/1959 BK 34 PG 177 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS SECOND ADDITION, BLOCK 1: LOTS 3 AND 4 CONTAINING .289254 ACRES 75058-01 THERESA R DECKER 03/07/1959 BK 34 PG 175 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 3 & 4 BLOCK 6: SOUTHERLY 8 FEET OF LOT 2 75059-00 WM R DEGRAW, ET UX 03/12/1959 BK 34 PG173 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 13 & 14 CONTAINING .13774 ACRES 75060-00 ROBERT A DEGRAW, ET UX 03/12/1959 BK 34 PG 171 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 10: LOTS 1,2,3 CONTAINING .20661 ACRES 75061-00 MARIE F IVERSON 03/12/1959 BK 34 PG 169 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 23,24,25, AND 26 CONTAINING .27548 ACRES 75062-00 NEIL HACKLIN, ET UX 03/18/1959 BK 34 PG 167 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK B: LOTS 13,14,15, AND 16 = .27598 AC 75063-01 ELLIS E ALEXANDER, ET UX 03/18/1959 BK 34 PG 165 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 1,2,3,4,5,6, AND 7 CONTAINING .48209 ACRES 75063-02 FRANK ZAGAR, ET UX 07/15/1959 BK 41 PG 104 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 3,4,5,6, AND 7 75064-00 GERALD C HALE, ET UX 03/18/1959 BK 34 PG 163 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 27, 28, 29, 30, 31 AND 32 CONTAINING .41322 ACRES 75065-00 JOHN E GAULT, ET UX 03/20/1959 BK 34 PG 161 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 8,9, AND 10 CONTAINING .20661 ACRES 75066-00 JOHN EDLUND, ET UX 03/20/1959 BK 34 PG 159 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 8-10 .20661 ACS. BLOCK 10: LOTS 11-14 AND 16 .34435 ACS. 75067-00 WALTER J CRANOR, ET UX 03/20/1959 BK 34 PG 157 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 9-11 .20661 ACS. BLOCK 8: LOTS 11-15 .34435 ACS 75068-00 HOLGER JOHNSON, ET UX 03/20/1959 BK 34 PG 155 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 13-16 .27548 ACRES 75069-00 JESSE R GAULT, ET UX 03/21/1959 BK 34 PG 153 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 5,6,7, AND 8 CONTAINING .27548 ACRES 75070-00 PETE SUNDGREN, ET UX 03/23/1959 BK 34 PG 151 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 6,7 & 8; .20661 AC. 75071-00 NORMAN KIEFFER, ET UX 03/23/1959 BK 34 PG 149 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 4 & 5; .13774 AC. 75072-00 ARVEL A DAVID, ET UX 03/23/1959 BK 34 PG 147 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 20-22 .20661 ACRES 75073-00 ERIC WALLIN 03/23/1959 BK 34 PG 145 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 12-13 .13774 ACS. 75074-00 JOHN PEARSON 03/23/1959 BK 34 PG 143 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOT 6 .06887 ACS. 75075-00 DONALD L STUDT, ET UX 03/23/1959 BK 34 PG 141 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOTS 7-11 .34435 ACS. 75076-00 GEORGE VICKREY, ET UX 03/25/1959 BK 34 PG 139 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 22-26 .34435 ACRES BLOCK 6: LOTS 18-19 .13774 ACRES BLOCK 7: LOTS 1-2 .13774 ACRES 75077-00 NELS OSTROM 03/26/1959 BK 34 PG 137 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 10 .06887 ACRES 75078-00 JOHN WESTERLUND 03/26/1959 BK 34 PG 135 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2, LOT 9 .06887 ACS. 75079-00 SAM OHME 03/26/1959 BK 34 PG 133 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 14; .06887 AC. 75080-00 RALPH V WHITE, ET UX 03/26/1959 BK 34 PG 131 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK E: LOTS 9,10,12,13; .309915 AC. 75081-00 CARL KULINSKY, ET UX 03/26/1959 BK 34 PG 127 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 1&2; .13774 AC. 75082-00 C E TALCOTT, JR, ET UX 03/26/1959 BK 34 PG 129 WY LINCOLN TO26N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOT 26; .06887 AC. 75083-00 OLIVER E GREGORY, ET UX 03/30/1959 BK 34 PG 125 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOTS 8,9,10,24,25; .34435 AC. 75084-00 J. THOMAS HALL, ET UX 03/30/1959 BK 34 PG 123 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 27,28 & 29; .20661 AC. 75085-00 PETE M GOLICH, ET UX 03/30/1959 BK 34 PG 121 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1, LOTS 1 AND 2 .13774 ACS. 75086-00 VINCENT A GUYETTE 03/30/1959 BK 34 PG 105 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK B LOTS 11 & 12 .13774 ACS. 75087-00 AARON NEALE JONES, ET UX 03/26/1959 BK 34 PG 119 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK D LOTS 1,2,3,4 .27548 ACS 75088-00 ALVIN VALLETT, ET UX 04/02/1959 BK 34 PG 117 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 2,3,4; .20661 AC. 75089-01 LESLIE C VASEY, ET UX 04/06/1959 BK 34 PG 115 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 3; .06887 AC SECOND ADDITION, BLOCK 3: LOTS 1 & 2; 1.61 AC. 75090-00 SCHOOL DISTRICT NO. 1 04/13/1959 BK 34 PG 113 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 1,2,3,4,5,6,7; .48209 AC. 75091-00 VIRGIL V BAILEY, ET UX 03/07/1959 BK 34 PG 97 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOT 14; .06887 AC. BLOCK 6: LOTS 5,6,7,8,9 AND 10; .41322 AC. BLOCK 7: LOT 16; .06887 AC. 75092-00 DON WAGNER, ET UX 04/20/1959 BK 34 PG 111 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 30, 31 & 32; .20661 AC. 75093-00 JIMMY DE GRAW, ET UX 04/06/1959 BK 33 PG 419 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS 75094-00 VELMA WILSON, ET AL 04/20/1959 BK 34 PG 109 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 11; .06887 AC. 75095-00 HERMAN PIZ, ET AL 04/22/1959 BK 34 PG 107 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 3; LOTS 13 & 14; .41322 AC. 75096-00 GORDON GUYETTE, ET UX 06/02/1959 BK 34 PG 103 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK D: LOT 7; .06887 AC. 75097-00 ALEX J BERTAGNOLLI 05/09/1959 BK 34 PG 99 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 1,2,3,17,18,19,20 & 21; .55096 AC. 75098-00 PAUL I BERTAGNOLLI, ET UX 06/04/1959 BK 34 PG 101 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 4 & 5; .13774 AC. 75099-01 C.J. YATES 10/31/1959 BK 41 PG 98 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOT 26 75100-00 LEO MANSKE, ET UX 10/12/1959 BK 41 PG 100 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 12,13,14 & 16 75110-00 USA WYW-124999 10/01/1991 BK303 PG 145 WY LINCOLN T025N R112W SEC-0022 ALL 75148-00 USA WYW-125960 01/01/1992 BK314 PG 43 WY LINCOLN TO25N R112W SEC-0024 LOT 1 75158-00 USA WY-42788 01/01/1974 BK314 PG 223 WY LINCOLN TO25N R112W SEC-0024 W2NE, W2SE, LOTS 2,3,4 T025N R112W SEC-0025 N2NW, SENW, SW, SWNW, W2NE, W2SE, LOTS 1,2,3,4 75174-00 USA EV-07675(C) 11/01/1965 BK 88 PG 535 WY SUBLETTE T027N R113W SEC-0034 E2E2 BK311 PG 679 WY LINCOLN T026N R113W SEC-0003 LOT 1 75175-00 USA EV-07798(C) 09/01/1964 BK311 PG 221 WY LINCOLN T026N R113W SEC-0003 SWSE T026N R113W SEC-0010 W2SW 75176-00 USA EV-07798(D) 09/01/1964 BK311 PG 226 WY LINCOLN TO26N R113W SEC-0003 E2SE, LOTS 8 AND 9 T026N R113W SEC-0010 E2SW, N2NE 75177-00 USA EV-08051(A) 02/01/1948 BK 88 PG 511 WY SUBLETTE T027N R113W SEC-0027 NENW, W2SWNE 75178-00 USA EV-024168 11/01/1947 BK 36 PG 108 WY SUBLETTE T027N R113W SEC-0027 NWSE 75179-00 USA WY-040934 06/01/1956 BK 36 PG 222 WY SUBLETTE T027N R113W SEC-0027 NESE 75180-00 USA WY-041447 06/01/1956 BK 36 PG 227 WY SUBLETTE TO27N R113W SEC-0027 SESE 75181-00 USA WY-088274 07/01/1961 BK 50 PG 67 WY LINCOLN T026N R113W SEC-0002 SW 75182-00 USA WY-088275 07/01/1961 BK 50 PG 64 WY LINCOLN T026N R113W SEC-0002 W2SE, LOTS 13, 14 50002-00 ENGER K CHRISMAN 06/18/1947 BK 5 PG 3 WY SUBLETTE T029N R113W SEC-0010 SENE, NWSE 50004-00 USA W-10676 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0013 W/2 SW/4 S/2 NW/4, SW/4 NE/4, NE/4 SW/4 T029N R113W SEC-0023 W/2 W/2 50012-00 CLIFTON FEAR, ET AL 04/12/1955 BK 11 PG 449 WY SUBLETTE T029N R113W SEC-0009 E2SW, SE T029N R113W SEC-0010 SWNW, SWSE, SW T029N R113W SEC-0015 N2N2 50023-00 USA W-05689 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 W/2SWSW, E/2SWSW, SESW 50025-00 USA W-17208 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0032 LOTS: NE PART OF 17, 18, 19, 20 ALL LOT 17 EXCEPT NE 50030-00 USA W-21124 06/01/1951 BK 34 PG 174 WY SUBLETTE T030N R113W SEC-0004 LOTS 3, 4 T030N R113W SEC-0005 LOT 1, SENE, SW LOTS 2,3,4, SWNE, S2NW T030N R113W SEC-0006 SENE, NESE, LOTS 1,2, SWNE 50032-00 USA W-02736 12/01/1950 BK 33 PG 343 WY SUBLETTE T031N R113W SEC-0028 SWNW, NWSW T031N R113W SEC-0029 N2, SE, SW T031N R113W SEC-0031 E2NE, NESE LOTS 1-4, E2W2, W2NE, S2SE, NWSE T031N R113W SEC-0032 W2, W2SE, E2E2, W2NE T031N R113W SEC-0033 NWNW, S2NW, SW, SWNE, SE 50034-00 USA W-05958 07/01/1951 BK PG WY LINCOLN T025N R113W SEC-0031 S2 LOT 3, LOT 4, W2 LOT 5, SWNESW N2 LOT 3, E2 LOT 5, N2NESW, SENESW 50035-00 EDGAR F HERSCHLER ET UX 09/19/1953 BK 5 PG 398 WY LINCOLN T024N R114W SEC-0000 RESURVEY TRACT 50 BEING THE WEST 3/4 AND RESURVEY TRACT 55 BEING ALL RESURVEY TRACT 49 BEING THE WEST 40 ACRES 50036-00 ARNOLD A LARSON ET UX 09/18/1953 BK 5 PG 361 WY LINCOLN T024N R114W SEC-0000 TRACT 46-B (ORIGINALLY SESW SEC. 2) TRACT 45 BEING THE CENTER 1/3 (ORIGINALLY THE NWNW SEC. 11) TRACT 50 BEING THE MOST EASTERLY 1/4, ORIGINALLY SWNE SEC. 3 (42.79 AC) PORTION OF TRACT 48, ORIGINALLY SENE SEC. 3 (41.83 AC) TRACT 45 BEING THE MOST WESTERLY 1/3, ORIGINALLY NENE SEC. 10 TRACT 49 BEING THE MOST EASTERLY 80 ACRES, ORIGINALLY W2SE SEC. 3 T024N R114W SEC-0002 LOTS 16 (39.10), 17 (5.71), 18 (6.48) T024N R114W SEC-0003 LOTS 12 (22.51), 13 (20.35) LOTS 14 (17.84), 18 (17.84) 50037-00 ST WY 08945 09/16/1949 BK 5 PG 382 WY LINCOLN T025N R114W SEC-0036 SESE LOT 40, E2SWSE LOT 40 ALL LESS AND EXCEPT SESE LOT 40, E2SWSE LOT 40 50038-00 USA W-01902 03/01/1950 BK 10 PG 134 WY LINCOLN T024N R114W SEC-0003 W2 LOT 10 AND LOT 11, E2 LOT 10 50039-00 USA EV-024522-A 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 SESE 50040-00 USA EV-024521-A 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 SESE 50041-00 USA EV-024522 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0015 SENW, S2NE, SE, E2SW, N2N2, SWNW, E2SW T023N R112W SEC-0021 NE, N2SE, SWSE T023N R112W SEC-0028 NE 50042-00 USA EV-24521-B 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 N2, N2S2, S2SW, SWSE T023N R112W SEC-0023 NWNW, NE, NENW, S2NW, S2 T023N R112W SEC-0027 NW, N2NE 50059-00 CHAMPLIN PETROLEUM CO. 10/03/1973 BK108 PG 437 WY LINCOLN T022N R112W SEC-0021 E2SW, SE, SENW, S2NE 50065-00 USA W-0127851 10/01/1961 BK PG WY SUBLETTE T030N R113W SEC-0013 SWNE, SE 50066-00 USA W-02274 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NENW, S2NW T030N R113W SEC-0024 SE, NESW, E2NE, NWNE, E2NW 50067-00 USA W-02274-A 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NWNW 50068-00 USA EV-024526-G 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENW 50069-00 USA W 16769 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 LOTS 1,2,3,4 50070-00 USA W-05504 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0014 E2NE, NESE 50071-00 USA EV-024538-A 12/01/1948 BK PG WY SUBLETTE T030N R113W SEC-0013 SW4 50075-00 USA EV-024354 11/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0034 ALL T029N R112W SEC-0033 E2NE, SE 50076-00 ANDERSON L MCGINNIS 06/01/1953 BK 86 PG 492 WY SUBLETTE T028N R112W SEC-0019 LOT 2, SENW 50077-00 WILLIAM J MCGINNIS 03/12/1963 BK 36 PG 119 WY SUBLETTE T028N R112W SEC-0017 S2N2, N2SW, NWSE, SWSW T028N R112W SEC-0018 SE, SESW, LOT 4 T028N R112W SEC-0019 NWNE 50078-00 USA EV-024355 09/01/1949 BK PG WY SUBLETTE T029N R112W SEC-0032 E2, E2W2 T029N R112W SEC-0033 W2, W2NE 50082-00 USA EV-024470 01/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0027 ALL T029N R112W SEC-0028 SWSE, S2SESE, E2SESW, W2SESW, N2SESE, NW, NE, N2S2, SWSW T029N R112W SEC-0029 W2SW, NE, NW, SE, E2SW 50084-00 USA W-53496 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0029 W2E2, SW, E2NW, SWNW, NWNW T028N R112W SEC-0030 SE, LOT 2 (33.12 ACS), LOT 3 (32.59 ACS), LOT 4 (32.24 ACS), NE, E2W2 T028N R112W SEC-0031 NE, LOT 1 (31.93 ACS), LOT 2 (31.68 ACS), LOT 3 (31.42 ACS), SE, E2W2 T028N R112W SEC-0032 W2NW 50085-00 USA W-53498 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 W2NE, NWSE, E2NW, E2NESW, SWSE, S2SW, W2NESW 50087-00 USA W 92216 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0005 LOTS 1-12 S2 T028N R112W SEC-0006 LOTS 1, 3-18, E2SW, SE T028N R112W SEC-0007 LOTS 1-4, E2, E2W2 50089-00 USA W 92219 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 N2NWSW, W2 LOT 4(19.19), LOT 5(40.0), LOT 12(40.0) E2 LOT 4, S2NWSW 50093-00 USA EV-022234 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0020 LOT 5 T028N R113W SEC-0029 NE/4; E/2 NW/4; NE/4 SW/4; N/2 SE/4; SE/4 SE/4 50097-00 USA EV-023584 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0023 LOT 4 (27.24), W2NW 50099-00 USA EV-024353 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 LOTS 6,7,8, E2SW, SWSE, TRACT 43-B 50103-00 USA W-0256492 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0021 LOT 7, TRACTS 43-A, 43-C T028N R113W SEC-0028 LOTS 2,3,4,9,10, TRACTS 50-B, 50-D, LOT 11 50107-00 USA W-0637 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0015 SE, SWNE, W2 50111-00 USA EV-022239 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0008 E2, E2W2 50112-00 RUTH A CHAMBERLAIN, ET VIR 01/17/1950 BK 2 PG 295 WY SUBLETTE T028N R113W SEC-0020 E2NE T028N R113W SEC-0021 W2NW 50118-00 WILLIAM J MCGINNIS, ET AL 07/30/1947 BK 2 PG 158 WY SUBLETTE T028N R113W SEC-0021 TRACT 42 50124-00 USA EV-022241 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0022 W2SW, SESW, N2, LOT 1, NESW, NWSE T028N R113W SEC-0027 S2SW 50125-00 MARY H MCGINNIS 07/01/1946 BK 2 PG 101 WY SUBLETTE T028N R113W SEC-0027 RESURVEY TRACT 48 50128-00 USA W-48908 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0017 LOTS 1,3,4,5,6, SWNE, NWSE T028N R113W SEC-0021 LOTS 1,2,3,4,5,6,8, S2NE, N2SE, SESE, TR 43-D T028N R113W SEC-0028 LOTS 1,5,6,7,8, TRS 50-A & 50-C, S2SE T028N R113W SEC-0031 LOTS 7,8 T028N R113W SEC-0032 TR 53 50130-00 USA EV-07538 01/01/1940 BK 89 PG 76 WY SUBLETTE T028N R113W SEC-0033 NWNW 50132-00 USA W-031454 03/01/1955 BK PG WY LINCOLN T026N R113W SEC-0009 E/2 50146-00 USA W-0256491 01/01/1940 BK PG WY SUBLETTE T028N R113W SEC-0033 NENW 50191-00 USA EV-024966-A 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 NWNW 50196-00 USA W-0125390 06/01/1955 BK PG WY SUBLETTE T029N R112W SEC-0030 LOTS 1, 2, 3, 4, E2W2, NWNE, S2NE, SE T029N R112W SEC-0031 E2W2, E2, LOTS 1, 2, 3, 4 50197-00 USA W-0125391 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOTS 5 (39.18 AC), 6 (38.97) 50199-00 USA W-0189 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 N2NE4 50200-00 USA W-014052 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 LOTS 7(40.43 ACS), 8(39.46) 50201-00 USA EV-026216 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2SW 50202-00 USA W-10680 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 7 50205-00 ST WY 0-10799 03/02/1951 BK PG WY SUBLETTE T029N R113W SEC-0001 NENE T030N R113W SEC-0036 ALL 50206-00 USA W 21125 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 W2 T030N R113W SEC-0015 SWSW T030N R113W SEC-0021 N2 50207-00 USA W21123 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 W2NW 50208-00 USA W-04628 02/01/1956 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, S2SE, W2NE, NWSE 50210-00 ST WY 0-13662 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 E2SW, SE 50211-00 ST WY 0-11311 07/02/1951 BK PG WY SUBLETTE T030N R113W SEC-0016 S2NE 50212-00 ST WY 0-13663 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 NW, W2SW 50220-00 USA W-04015-B 02/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2NENW, W2NENW 50223-00 USA EV-024526 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENWNE, NWNWNE, S2NWNE 50224-00 USA EV-026171 08/01/1950 BK PG WY SUBLETTE T030N R112W SEC-0018 SESW, LOTS 1,2,3,4, NWNE, S2NE, E2NW, NESW, SE T030N R112W SEC-0032 N2SW 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 NESW, SESW 50227-00 USA W-04101-B 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2SENW, W2SENW 50228-00 USA W-056555 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0008 NWNE, S2N2, LESS 6.37 AC INCL IN 67TH RESERVOIR T030N R112W SEC-0009 SW, W2SE, SESE T030N R112W SEC-0017 S2, S2N2 T030N R112W SEC-0020 W2W2, NENW T030N R112W SEC-0033 S2N2 50229-00 USA W-27641 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2, SENW 50230-00 USA W-055073 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0027 W2 T030N R112W SEC-0029 W2W2 T030N R112W SEC-0032 N2 T030N R112W SEC-0033 N2N2 T030N R112W SEC-0034 W2NW 50232-00 USA W-36567 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 N2NE, SWNE, NWSE 50233-00 USA W-027642 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENE, SENE 50235-00 ST WY 0-20914 08/16/1956 BK 16 PG 88 WY SUBLETTE T029N R112W SEC-0016 S2SW, NWSW, SWNW: LIMITED FROM SURFACE TO BASE OF MESAVERDE FORMATION (4,500'), SE, SWNE N2NE, SENE 50238-00 USA EV-024445-E 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 NE4NW4 50239-00 USA W-036663-A 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SESE 50240-00 USA EV-024445 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2SW4 50241-00 USA W-036663 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SENE, NESE 50250-00 USA W-43911 08/01/1956 BK PG WY SUBLETTE T029N R112W SEC-0013 SE, S2SW T029N R112W SEC-0024 W2NW, SW T029N R112W SEC-0025 N2NW 50253-00 USA W-53499 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0022 SWNW, S2, S2NE T029N R112W SEC-0023 NE, NWSE, E2SE, NW, N2SW T029N R112W SEC-0026 NENE 50261-01 FIRST NAT'L BNK OF KEMMERER 12/29/72 BK 48 PG 628 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9, 11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2, 5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50261-02 DANIEL E CHAPEL 03/07/1981 BK 61 PG 461 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9,11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2,5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50265-00 USA W-48517 01/01/1975 BK 68 PG 367 WY SUBLETTE T029N R112W SEC-0017 SENW, E2SW, SWSE 50330-00 ST WY #67-4099 04/02/1967 BK 42 PG 205 WY SUBLETTE T027N R112W SEC-0016 E2 BEING W2NE, SESE, LOTS 1-5, 7, PORTION LOT 6 IN SWSE (5.31 AC)-PORTION IN CONFINES GREEN RIVER BED 50332-00 USA W-05690 07/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0015 SWNW 50333-00 USA W-020778 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0035 E2, NW4 50335-00 USA W-05691 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0005 LOTS 5,6 50336-00 USA EV-021954 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0022 NWNE 50337-00 USA W-51101 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0003 S2S2 T027N R114W SEC-0004 S2 T027N R114W SEC-0005 LOTS 13,14,15,16, E2 LOT 23,24, W2 LOT 23 T027N R114W SEC-0009 NE, E2NW, N2SE, SESE T027N R114W SEC-0010 SWSW 50345-00 USA W-64986 09/13/1978 BK 74 PG 522 WY SUBLETTE T027N R112W SEC-0011 S2 T027N R112W SEC-0014 N/2 50356-00 USA W-0231770 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 NW4NW4 50357-00 USA W-0231771 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 W2SW4 50358-00 USA W-0231772 06/01/1952 BK 69 PG 549 WY SUBLETTE T028N R113W SEC-0002 SWNW, NWSW T028N R113W SEC-0003 NWSE, S2NE, NESE, LOTS 5 & 6 50359-00 USA W-024931-A 10/01/1948 BK PG WY SUBLETTE T029N R113W SEC-0025 SENW, SWNW 50360-00 USA EV-025930 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0023 E2W2 50361-00 USA W-031992 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0026 N2NE4, NE4NW4 50363-00 USA W-014051 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 8 50364-00 USA W-02683 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 E2SW, SWSE 50366-00 USA EV-021767 09/01/1950 BK 89 PG 10 WY SUBLETTE T029N R113W SEC-0035 SE4 50374-00 USA W-62801 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0007 LOTS 1 THRU 4, E2, E2W2 T031N R113W SEC-0018 LOTS 1 THRU 4, E2, E2W2 50380-00 USA W-60577 11/01/1977 BK 88 PG 764 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1,2,3,4, E2, E2W2 T028N R111W SEC-0031 NE, E2SE T028N R111W SEC-0032 W2 50422-00 USA W-11603 04/01/1968 BK PG WY SUBLETTE T028N R114W SEC-0021 NE, SE 50424-00 ST WY 66-5165 03/02/1966 BK PG WY SUBLETTE T028N R114W SEC-0016 NENE, NW, N2SW, SE, SENE, S2SW, W2NE 50425-00 USA W-2120 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0015 NW, SW T028N R114W SEC-0022 SW 50427-00 USA W-055275 02/01/1959 BK PG WY SUBLETTE T026N R112W SEC-0022 NW, N2SW, S2SW 50428-00 BETTE M THOMPSON 07/06/1976 BK 53 PG 154 WY SUBLETTE T029N R113W SEC-0004 W2SW, SESW T029N R113W SEC-0005 E2SE T029N R113W SEC-0007 NESE, E2NE T029N R113W SEC-0008 N2NE, W2NW, NWSW, NESW, SE SENE, SENW, S2SW T029N R113W SEC-0009 N2NW, S2NW, W2SW T029N R113W SEC-0017 E2NW, NWNE 50439-00 USA W-73977 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0017 NWNW, E2, E2NW, NESW T032N R114W SEC-0020 NE, N2SE 50507-00 USA W-67176 08/01/1979 BK223 PG 400 WY LINCOLN T026N R111W SEC-0006 SENW, SWNE, W2SE, LOTS 3,4,5,6,7 T026N R111W SEC-0007 W2E2 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW TO29N R113W SEC-0003 NESE 57132-00 MONTE NORRIS 03/12/1985 BK 74 PG 285 WY SUBLETTE T031N R113W SEC-0019 E2SW, S2SE, LOTS 2, 4 T031N R113W SEC-0030 NENW, N2NE T031N R114W SEC-0023 SENE T031N R114W SEC-0024 NW, N2SE, SESE, S2NE 58005-00 USA WYW-116385 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0019 LOTS 1,3, N/2NE, E/2NW T031N R113W SEC-0030 LOTS 1,2,3,4, E/2SW 58343-00 USA W-34033 05/01/1972 BK 57 PG 280 WY SUBLETTE T027N R111W SEC-0029 NENE 58344-00 USA W-35398 07/01/1972 BK 63 PG 605 WY SUBLETTE T027N R111W SEC-0008 SWSE T027N R111W SEC-0017 NE 58345-00 USA W-35399 07/01/1972 BK 64 PG 633 WY SUBLETTE T027N R111W SEC-0015 N2 58346-00 USA W-36422 10/01/1972 BK 57 PG 359 WY SUBLETTE T027N R111W SEC-0022 N2 T027N R111W SEC-0023 ALL T027N R111W SEC-0025 SE, W2 T027N R111W SEC-0026 ALL 58347-00 USA W-51347 08/01/1975 BK 61 PG 447 WY SUBLETTE T027N R111W SEC-0005 NW,SW T027N R111W SEC-0006 SE, S2NE T027N R111W SEC-0007 NE T027N R111W SEC-0008 NW, N2SW 58348-00 USA W-54136 04/01/1976 BK 64 PG 638 WY SUBLETTE T027N R111W SEC-0014 ALL T027N R111W SEC-0015 S2 58349-00 USA W-54137 04/01/1976 BK 64 PG 155 WY SUBLETTE T027N R111W SEC-0017 SE T027N R111W SEC-0020 NE 58350-00 USA W-58724 05/01/1977 BK 54 PG 470 WY SUBLETTE T027N R111W SEC-0019 LOTS 1-4, E2W2, W2SE, SWNE T027N R111W SEC-0030 LOTS 1-3, E2W2, E2 58351-00 USA W-59776 09/01/1977 BK 64 PG 278 WY SUBLETTE T027N R111W SEC-0020 NESW 58352-00 USA W-62117 02/01/1978 BK 60 PG 198 WY SUBLETTE T027N R111W SEC-0028 NW, N2SW, SESW 58353-00 USA W-62508 11/01/1978 BK 57 PG 187 WY SUBLETTE T027N R111W SEC-0029 SE, SENE, W2, W2NE 58354-00 USA W-62875 04/01/1978 BK 68 PG 533 WY SUBLETTE T027N R111W SEC-0030 LOT 4 58355-00 USA W-63490 06/01/1978 BK 66 PG 168 WY SUBLETTE T027N R111W SEC-0032 NW, N2SW, LOT 2 58356-00 USA W-63821 07/01/1978 BK 57 PG 195 WY SUBLETTE T027N R111W SEC-0032 LOTS 3 AND 4, N2SE, NE 58357-00 USA W-67808 06/01/1979 BK PG WY SUBLETTE T027N R111W SEC-0006 N2NE T027N R111W SEC-0007 SE T027N R111W SEC-0018 E2NE, E2SE T027N R111W SEC-0019 E2NE, E2SE 58358-00 USA W-68116 07/01/1979 BK708 PG1493 WY SWEETWATER T026N R111W SEC-0004 SW, LOTS 1-4, S2N2, SE T026N R111W SEC-0010 S2N2 58359-00 USA W-68117 07/01/1979 BK 59 PG 7 WY SUBLETTE T027N R111W SEC-0008 S2SW T027N R111W SEC-0017 W2 T027N R111W SEC-0020 NW, NWSW, SE, S2SW 58360-00 USA W-68454 09/01/1979 BK 71 PG 306 WY SUBLETTE T027N R111W SEC-0028 SWSW 58960-00 USA WYW-034924 04/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0023 SWNE 58961-00 USA WYW-034927 05/01/1948 BK PG WY SUBLETTE T027N R114W SEC-0001 W2SW 58962-00 USA WYW-034930 10/01/1950 BK 86 PG 232 WY SUBLETTE T027N R114W SEC-0022 NENE T027N R114W SEC-0023 NW, NWNE 58963-00 STATE OF WYOMING #0-20476 01/16/1956 BK150 PG 285 WY SUBLETTE T028N R114W SEC-0036 N2, N2S2, S2SW 59023-00 USA EV-026053 10/01/1949 BK 86 PG 283 WY SUBLETTE T029N R113W SEC-0035 NE 59041-00 STATE OF WYOMING #0-11193 05/16/1951 BK 3 PG 350 WY SUBLETTE T029N R113W SEC-0036 ALL 75114-00 USA WY-0311662 10/01/1964 BK 38 PG 373 WY SUBLETTE T028N R114W SEC-0005 LOTS 9, 10, 14, 15, 16, 17, 18, 19 T028N R114W SEC-0008 LOTS 2, 3, 4, 5, 6, 7, 8, 9, 10 11,12,13,14,15,16,17,18,19,20 T028N R114W SEC-0021 SESW, W2SW 75116-00 USA WY-51104 04/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0017 LOT 4 T208N R115W SEC-0012 NW 75117-00 USA WY-42791 01/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0005 LOTS, 7, 8, 12 T028N R114W SEC-0021 NESW, N2NW, SENW 75118-00 USA WY-51103 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0017 LOTS 1,2,3,5,6,7,8,9,10,11, 12,13,14,15,16,17,18,19,AND 20 75119-00 USA WY-320213 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0020 LOTS, 1,2,3,4,5,6,7,8,9 10 11,12,13,14,15,16,17,18,19,AND 20 75120-00 USA WY-52811 12/01/1975 BK PG WY SUBLETTE T028N R114W SEC-0022 NW 75123-00 USA WY-38076 02/01/1973 BK PG WY SUBLETTE T028N R114W SEC-0009 W2SE, E2SE, N2SW T028N R114W SEC-0010 SW 75124-00 USA WY-9578 12/01/1967 BK PG WY SUBLETTE T208N R114W SEC-0003 LOTS 7 THRU 10 LOTS 15 THRU 18 T028N R114W SEC-0004 LOTS 5 THRU 20 T028N R114W SEC-0005 NWSE, S2NE, LOTS 5, 6, 13, 20 T028N R114W SEC-0009 N2 T028N R114W SEC-0010 NW 50006-00 USA W-125389 09/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0019 LOTS 3(12.53) 4(12.13). E/2SW SWSE LOT 2(12.63). NENE,S2NE, N2SE, SESE, SENW 50007-00 USA W-0231774 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 S2NE, N2SE, S2SE 50009-00 USA W-0231773 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 S2NW, N2SW, S2SW 50010-00 USA EV-022755 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0011 W2 50014-00 USA W-10674 12/31/1938 BK 88 PG 775 WY SUBLETTE T029N R113W SEC-0014 SENE, E2SE T029N R113W SEC-0015 S2N2, S2 50016-00 USA W-085597 (ROW) 01/01/1958 BK PG WY SUBLETTE T027N R113W SEC-0018 SENW (ROW) 50017-00 USA EV-024756-A 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0024 LOT 2 50024-00 USA W-20039 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0033 SWNE 50026-00 USA W-054585 07/01/1951 BK PG WY SUBLETTE T027N R113W SEC-0012 NENW, SWSW 50043-00 USA W-71775 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0027 NESW, SE, SESW, S2NE, W2SW 50044-00 USA W-71776 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0028 NESW, NW, SE, SESW 50045-00 USA W-92975 11/011948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 W2 T023N R112W SEC-0028 W2SW 50055-00 USA EV-025548 01/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0026 ALL T027N R112W SEC-0027 E2 50056-00 USA W-05923 06/01/1951 BK PG WY SUBLETTE T022N R112W SEC-0009 S2 50057-00 USA W-45370 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0020 E2SW, SE, SENW, S2NE T022N R112W SEC-0021 NWSW, SWNW 50058-00 USA W-45371 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0028 NWNW 50060-00 USA W-0319563 10/01/1965 BK PG WY LINCOLN T022N R112W SEC-0034 NW 50061-00 USA W-05924 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0015 N2S2, SWSW T022N R112W SEC-0022 N2, S2, T022N R112W SEC-0026 NE 50062-00 USA W-05925 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0026 N2SE, SWSE, W2 T022N R112W SEC-0028 E2, E2W2, SWNW, W2SW 50063-00 USA W-71772 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0010 SE, E2SW, NWSW, SWSW T022N R112W SEC-0020 W2W2, NENW, N2NE T022N R112W SEC-0021 N2N2 50064-00 USA W-71773 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0029 NWNW 50072-00 USA EV-024528 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0028 SENE, W2NE, W2, SE T028N R112W SEC-0029 E2E2 50073-00 USA W-035077 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 E2E2 50074-00 USA EV-024469 12/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0017 N2NE, E2SE, SWSE T028N R112W SEC-0020 E2NE, W2NE, SE T028N R112W SEC-0021 ALL 50079-00 USA EV-024735 01/01/1949 BK PG WY SUBLETTE T028N R112W SEC-0006 W2 LOT 2 E2 LOT 2 50080-00 USA EV-026175 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 LOTS 1,2,3,6,7,8,9,10,11,SE,E2SW,SWSW 50081-00 USA EV-023340 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0008 NW, W2SW 50086-00 USA W-53497 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0008 E2, E2SW T028N R112W SEC-0009 N2, S2 50092-00 USA EV-020363 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0032 LOTS 2,5 50095-00 USA EV-022281 07/01/1948 BK 32 PG 690 WY SUBLETTE T028N R113W SEC-0027 LOTS 1,4,5,7,8 50096-00 USA EV-022285 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0009 ALL 50098-00 USA EV-023969 07/01/1948 BK 32 PG 37 WY SUBLETTE T028N R113W SEC-0008 W2W2 T028N R113W SEC-0027 LOTS 2,3, T028N R113W SEC-0029 W2NW 50100-00 USA EV-025535 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0010 W2 50104-00 USA EV-025992 03/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0027 SWNW 50105-00 USA WY 0516 05/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0033 E2 50106-00 USA W-0636 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0005 SW, SWNW 50108-00 USA CH-082277 06/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0028 S2NE4, SE4 50109-00 ST WY 0-7395 09/16/1948 BK PG WY SUBLETTE T029N R113W SEC-0016 E2, NW, SW 50110-00 WILLIAM J. MCGINNIS ET AL 07/30/1947 BK 2 PG 162 WY SUBLETTE T028N R113W SEC-0017 TRACT 38 (AKA NESW) TRACT 40 (AKA SWSE) 50114-00 ST WY #0-04732 09/16/1944 BK 36 PG 155 WY SUBLETTE T028N R113W SEC-0016 ALL (RESURVEY TRACT 37) 50115-00 USA W-04732 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0004 LOTS 7,8, S2NW, SW 50116-00 USA W-026038-A 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0021 E2 T029N R113W SEC-0027 NWNW T029N R113W SEC-0028 N2NE 50117-00 USA W-0195876 02/01/1962 BK PG WY SUBLETTE T029N R114W SEC-0025 E2NE 50119-00 USA W-04731 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0005 LOTS 5,6,7,8, S2NE, SE, SENW 50120-00 ANDERSON L. MCGINNIS ET UX 07/30/1947 BK 2 PG 156 WY SUBLETTE T028N R113W SEC-0027 PT OF TRACT 49 (W2NW, SENW) T028N R113W SEC-0028 PT OF TRACT 49 (NENE) 50121-00 MARY J. HADDENHAM 07/30/1947 BK PG WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW, (RESURVEYED AND DESCRIBED AS TRACT 39) 50122-00 MARY J. (B) HADDENHAM 07/30/1947 BK 2 PG 153 WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW (RESURVEYED AND DESCRIBED AS TRACT 39) 50123-00 USA EV-025771 01/01/1948 BK 32 PG 55 WY SUBLETTE T028N R113W SEC-0022 LOT 2 T028N R113W SEC-0026 LOT 2, SWNW, W2SW 50126-00 USA W-48905 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0016 LOTS 1 THRU 7 T028N R113W SEC-0017 NWNE T028N R113W SEC-0020 LOTS 2,3,4, S2NW T028N R113W SEC-0029 SWSE, SESW 50127-00 USA W-48906 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 NWSW 50129-00 USA W-70864 10/17/1980 BK PG WY SUBLETTE T028N R113W SEC-0028 SENE-50 FT R-O-W 50148-00 USA EV-09561-B 04/23/1935 BK PG WY SUBLETTE T027N R113W SEC-0017 W2NW 50189-00 USA W-0136175 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0026 SW T030N R113W SEC-0027 E2NE, W2NE 50190-00 USA W-0136177 04/01/1951 BK 47 PG 103 WY SUBLETTE T030N R113W SEC-0022 SE 50192-00 USA W-27645 04/01/1951 BK 47 PG 103 wy SUBLETTE T030N R113W SEC-0010 W2SE, SW, NWNW, E2SE, NE, NENW, S2NW T030N R113W SEC-0014 S2SW, SWSE, N2SW, NWSE, SESE, W2NE, NW T030N R113W SEC-0022 NE, E2NW 50193-00 USA W-27644 08/01/1950 BK PG WY SUBLETTE T030N R1113W SEC-0011 NE, SE T030N R1113W SEC-0024 W2NW, NWSW, S2SW 50194-00 USA EV-024966 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 E2NE, E2NW, E2SE, SW, SWNW, W2NE, W2SE 50203-00 USA W-0231769 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2NW4 50204-00 USA EVANSTON 024241 05/01/1948 BK 18 PG 92 WY SUBLETTE T028N R113W SEC-0001 LOTS, 5,6, 9, 10, 11, SWNE, W2SE T028N R113W SEC-0012 LOTS 1-4, W2E2, W2 T028N R113W SEC-0013 LOTS 1-3, W2E2, NW 50208-00 USA W-04628 02/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, NWSE, S2SE, W2NE 50209-00 USA W-27643 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 SENW, E2SW 50217-00 USA W-16770 12/10/1948 BJ PG WY SUBLETTE T029N R112W SEC-0006 LOT 5, SENW, S2NE, NWSE T030N R112W SEC-0030 SWNE, LOTS 1-4, SE T030N R112W SEC-0031 LOTS 3, 4, E2SW, N2SE, SESW, SESE LOTS 1, 2, E2NW, NE 50219-00 USA W-053447 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0023 S2SW, SWSE 50225-00 USA W-039908 08/01/1956 BK PG WY SUBLETTE T029N R112 SEC-0024 E/2NW, E/2 T029N R112 SEC-0025 S/2, S/2N/2, N/2SE T029N R112 SEC-0035 ALL 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0020 E2NE T030N R112W SEC-0029 NESW, SESW 50259-00 YOSE CATTLE COMPANY 12/17/1981 BK 64 PG 76 WY SUBLETTE T027N R112W SEC-0003 LOTS 2(34.31 ACS); 3(39.72 ACS); 4(39.71 ACS) 5(45.51 ACS); EXCEPTING FRACTIONAL PARTS OF LOTS 3, 4, & 5, MORE FULLY DESCRIBED IN LEASE T028N R112W SEC-0026 S/2 SW T028N R112W SEC-0034 W/2,W/2; NENW; E/2 SW; W/2 SE; SENE; NESE LOT 1 (23.57 ACS) T028N R112W SEC-0035 LOT 4(41.92 ACS); W/2 NW; NWSE LOT8 (35.13 ACS) 50263-00 USA W-077883 07/01/1976 BK PG WY SUBLETTE T028N R111W SEC-0019 LOTS 2,3,4,E2,E2NENW, SWNENW,E2SW T028N R111W SEC-0020 E2 T028N R111W SEC-0029 SE, NE T028N R111W SEC-0032 NE, SE 50266-00 USA W-87038 09/01/1984 BK PG WY SUBLETTE T029N R112W SEC-0011 SWSW 50289-01 A L MAHAFFEY 12/26/1956 BK20PR PG 282 WY LINCOLN T026N R112W SEC-0006 PART OF SEC 6 & 7 T026N R112W SEC-007 PART OF SEC 6 & 7 50289-02 BABE PROBASCO ET UX 12/27/1956 BK 21 PG 31 WY LINCOLN T026N R112W SEC-0006 BEGIN 148' N SWSE S6 THEN E 610',THEN S 148' THE E ON SEC LINE BTWN S6&7 FOR 433';THEN N 835';THEN W 1043.5';THEN S 687'TO POINT OF BEGINNING 50131-01 HOWARD A. MAHAFFEY 12/26/1956 BK 20 PG 278 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION 50314-00 GUY DECKER ET UX 03/17/1957 BK 32 PG 377 WY LINCOLN T026N R112W SEC-0006 LOT 11 OF LOT 8,LOT 1 OF BLOCK 1 OF SECOND ADDITION TO TOWN OF LABARGE 50137-00 LINCOLN COUNTY #1 05/08/1957 BK 22PR PG 166 WY LINCOLN T000N R000W SEC-0000 LARGE TOWNLOTS;ORIG TOWNSITE;TULSA-BK9 LOTS 4-7;1ST ADD;TULSA-BK 12, LOTS 13-15 RIVERVIEW ADD-TULSA - BK A,LT15,-BK B, L1-4,-BK C, L13, 20, 35 - BK E, L15, 16, 19,& 20 50326-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 172 WY LINCOLN T000N R000W SEC-0000 STREETS & ALLEYS IN LABARGE,WY ORIG PLATTED TULSA, WY SHOWN ON LINCOLN M/B MAP #1&2 SEE LST FOR LST OF STREETS & ALLEYS 50328-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 176 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0007 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0018 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0019 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0020 SEE LEASE FORE METES AND BOUNDS DESCRIPTION 50334-00 USA W-8140 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0002 LOTS 1,2,3,4, S2N2, S2 (ALL) T027N R114W SEC-0003 LOTS 1,2,3,4, S2N2, N2S2 T027N R114W SEC-0004 LOTS 1,2,3,4, S2N2 T028N R114W SEC-0034 S2NE, SENW, S2 T028N R114W SEC-0035 SW 50338-00 USA W-72405 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0009 W2NW 50339-00 USA W-92223 07/01/1951 BK 65 PG 466 WY SUBLETTE T027N T114W SEC-0010 S2NE, NW, E2SW, NWSW, SW, N2NE T027N R114W SEC-0011 W2SW, N2, SE, E2SW T027N R114W SEC-0012 W2NW, NWNSW T027N R114W SEC-0014 SWNE, NW, S2, N2NE, SENE T027N R114W SEC-0015 NE, E2NW, NWNW 50340-00 USA W092222 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0015 NESW, SE 50341-00 USA W-96755 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0027 SE4 50342-00 USA W-96756 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 SE T028N R114W SEC-0034 N2N2, SWNW 50382-00 USA W-42781 01/01/1974 BK PG WY SUBLETTE T027N R111W SEC-0004 N2 T027N R111W SEC-0005 E2 T027N R111W SEC-0008 NE, N2SE. SESE T027N R111W SEC-0009 E2, W2 50421-00 USA W-20038 03/01/1969 BK PG WY SUBLETTE T027N R1114W SEC-0028 E/2NE4, NW/NE, NW/SE 50423-00 USA W-054586 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0015 NE, E2SE T028N R114W SEC-0022 E2NE, SE T028N R114W SEC-0027 W2NE, SENE 50426-00 USA W-2121 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0028 SWNE 50433-000 THEODORE JORDAN, ET AL 08/19/1954 BK 10 PG 170 WY SUBLETTE T029N R113W SEC-0004 S2SE4 T029N R113W SEC-0009 NE T029N R113W SEC-0010 N2NW, SENW 50437-00 USA W-19959 08/01/1969 BK 2 PG WY SUBLETTE T032N R114W SEC-0008 S2NW, N2SW LOTS 3, 4, S2SW 50438-00 USA W-06009 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0007 LOTS 1 (10.71) 2, (10.05) S2NE 50454-00 USA W-0320844 12/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0033 NWNW 50505-00 USA W-38503 03/01/1973 BK103 PG 402 WY LINCOLN T026N R111W SEC-0005 LOTS 1 & 2, S2NE, SE T026N R111W SEC-0008 E2 50506-00 USA W-57837 03/01/1973 BK552 PG 318 WY SWEETWATER T026N R111W SEC-0009 ALL 56833-00 USA W-85884 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0030 SENW 56931-00 USA W-107069 01/01/1988 BK 80 PG 747 WY SUBLETTE T031N R114W SEC-0013 N2, N2SW, SESW, SE T031N R114W SEC-0014 NW T031N R114W SEC-0023 NESW, S2SW T031N R114W SEC-0024 SW T031N R114W SEC-0025 W2E2, NW, SESE 57396-00 USA WYW-112556 08/01/1988 BK PG WY SUBLETTE T029N R112W SEC-0009 SESW, SWSE T029N R112W SEC-0010 S/2S/2 T029N R112W SEC-0015 ALL 57427-00 USA W-113137 10/01/1988 BK 81 PG 756 WY SUBLETTE T032N R114W SEC-0025 E/2, SENW, SW 57543-00 USA W-113659 12/01/1988 BK 89PR PG 89 WY LINCOLN T026N R113W SEC-0032 S/2NE, NW, N/2SW, SWSW, SE T026N R113W SEC-0033 SWNW, S/2 57544-00 USA W-113654 12/01/1988 BK267PR PG 383 WY LINCOLN T025N R113W SEC-0017 ALL T025N R113W SEC-0020 ALL T025N R113W SEC-0021 ALL 57545-00 USA W-113651 12/01/1988 BK267 PG 391 WY LINCOLN T025N R113W SEC-0004 NENE T025N R113W SEC-0005 E2, N2NW T025N R113W SEC-0006 LOTS 1, 6, 10, E2 T025N R113W SEC-0007 LOTS 3, 4, 6, THRU 12, NENE, SE, S2NE T025N R113W SEC-0008 NE, N2SE, SW, SWSE, S2NW T025N R113W SEC-0009 NESW, S2SW, W2NW 57546-00 USA WYW-113644 12/01/1988 BK 82 PG 153 WY SUBLETTE T028N R112W SEC-0032 NWSW 57547-00 USA WYW-113645 12/01/1988 BK 82 PG 165 WY SUBLETTE T029N R112W SEC-0017 NENW, SWNW, W/2SW T029N R112W SEC-0020 NENW T029N R112W SEC-0026 W/2NE, SENE, W/2, SE T029N R112W SEC-0030 NENE 57548-00 USA W-113661 12/01/1988 BK 82 PG 250 WY SUBLETTE T029N R113W SEC-0001 LOT 2, SWNE T029N R113W SEC-0006 LOTS 1 THRU 4 T029N R113W SEC-0007 LOT 3, 4, E/2SW, W/2SE, SESE 57641-00 USA WYW-114579 02/01/1989 BK 82 PG 446 WY SUBLETTE T027N R112W SEC-002 THAT PORTION OF GREEN RIVER RIPARIAN TO LOT 5, BEING MORE PARTICULARLY DESCRIBED ON LEASE 57824-00 USA WY-115956 06/01/1989 BK 83 PG 364 WY SUBLETTE T028N R112W SEC-0010 S/2NE, SE T028N R112W SEC-0011 SWNW, NWSW 57825-00 USA WYW-115961 06/01/1989 BK 83 PG 373 WY SUBLETTE T030N R113W SEC-0007 E/2SE T030N R113W SEC-0008 NWSW T030N R113W SEC-0018 NENE 57826-00 USA WYW-115960 06/01/1989 BK 83 PG 379 WY SUBLETTE T028N R113W SEC-0013 LOT 4 T028N R113W SEC-0024 LOT 1 57952-01 DUANE HARWARD ET UX TRUST 04/21/1989 BK275PR PG 142 WY LINCOLN T026M R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF THE REGISTER OF DEEDS, LINCOLN COUNTY, WY. 57952-02 DIAMOND H RANCH, INC. 02/28/1989 BK275PR PG 488 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT, MORE FULLY DESCRIBED IN BOOK 21 PAGE 143 AND LESS THE EUBANK FOOTHILL ESTATES,MORE FULLY DESCRIBED AT PLAT #314 OF THE OFFICE OF THE REGISTER OF DEEDS, LINCOLN CO., WY. 57952-03 WILLIAM B SPENCER ET UX 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-04 MARY H LAMBERT ET AL 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO.,WY 57952-05 ISABEL H SPENCER TRUST 04/21/1989 BK275PR PG 148 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-06 WILLIAM B SPENCER TRUST 04/21/1989 BK275PR PG 146 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-07 JEAN S STEPHENS 04/21/1989 BK275PR PG 150 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-08 GLENISLA HUNTER ET AL 04/21/1989 BK275PR PG 152 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT, MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-09 LOIS S BRADY 04/21/1989 BK275PR PG154 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-10 EUBANK CATTLE COMPANY 05/30/1989 BK276PR PG 303 WY LINCOLN T026N R112W SEC-0019 TRACT OF LAND IN SESW, S/2SE, KNOWN AS THE EUBANK FOOTHILL ESTATE, RECORDED AT PLAT #314 IN OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 58055-05 MILLER ROBERT M JR ET UX 06/22/1989 BK 83 PG 679 WY SUBLETTE T029N R112W SEC-0004 W/2SW T029N R112W SEC-0005 E/2SE, SWSE T029N R112W SEC-0008 E/2 T029N R112W SEC-0009 W/2W/2 58188-00 USA WYW-117869 11/01/1989 BK 85 PG 426 WY SUBLETTE T027N R112W SEC-0002 BED OF GREEN RIVER RIPARIAN TO LOTS 6 - 8 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0003 BED OF GREEN RIVER RIPARIAN TO LOTS 1, 6, 7, 10, 11 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0034 BED OF GREEN RIVER RIPARIAN TO LOT 2 ***SEE LEASE FOR COMPLETE DESCRIPTION*** 58189-00 USA W-117878 11/01/1989 BK 84 PG 606 WY SUBLETTE T031N R114W SEC-0009 S/2 T031 R114W SEC-0010 N/2 T031N R114W SEC-0014 N/2SW 58190-00 USA WYW-117867 11/01/1989 BK 85 PG 419 WY SUBLETTE T028N R111W SEC-0003 SW T018N R111W SEC-0002 ALL T028N R111W SEC-0027 ALL 58193-00 STATE OF WY-8900650 10/02/1989 BK 84 PG 614 WY SUBLETTE T031N R114W SEC-0016 W/2 58419-00 STATE OF WYOMING #89-00780 12/02/1989 BK 85 PG 389 WY SUBLETTE T030N R112W SEC-0016 ALL 58420-00 STATE OF WYOMING #89-00781 12/02/1989 BK 85 PG 39 WY SUBLETTE T030N R112W SEC-0028 S/2NE 58421-00 STATE OF WYOMING #89-00782 12/02/1989 BK 85 PG 393 WY SUBLETTE T030N R112W SEC-0032 NESE, SWSE 58423-00 USA WY-95121 11/01/1985 BK 84 PG 623 WY SUBLETTE T030N R112W SEC-0007 LOTS 2, 3, 4,, W/2NE, SENE, E/2SW, (LESS 6 ACRES) T030N R112W SEC-0027 SWSE T030N R112W SEC-0032 NWSE 58424-00 USA WYW-118696 01/01/1990 BK 85 PG 382 WY SUBLETTE T031N R114W SEC-0005 LOT 4(41.15), SWNW, NWSW, S/2S/2 T031N R114W SEC-0008 NE, S/2 T031N R114W SEC-0017 ALL T031N R114W SEC-0020 ALL 58521-00 GORDON W BRAY, ET UX 11/10/1989 BK 84 PG 653 WY SUBLETTE T030N R112W SEC-0026 W/2SW, SWNW T030N R112W SEC-0027 S/2NE, N/2SE, SESE T030N R112W SEC-0034 N/2NE, E/2NW 58551-00 USA W-106177 11/01/1987 BK PG WY SUBLETTE T030N R112W SEC-0015 NWNW T030N R112W SEC-0017 N/2NW (LESS 1.37 ACRES, MORE OR LESS IN T030N R112W SEC-0020 W/2E/2, SENW, NESW 58561-01 HELEN JENKINS O'NEIL 12/12/1989 BK 85 PG 91 WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58561-02 MIRIAM JENKINS BAILEY 12/11/1989 BK 85 PG 87 WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW,S/2 58561-03 JOHN PERRY BARLOW, ET UX 12/11/1989 BK 85 PG WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58562-00 BRUCE E JONES ET UX 11/13/1989 BK281PR PG 592 WY LINCOLN T025N R113W SEC-0006 LOTS 3(17.85),4(17.00),5(40.00),7(40.00), 11(40.00) 59157-01 PAUL HOMER, ET UX 05/22/1990 BK 86 PG 559 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-02 WILLIAM CHARLES CHRISTY 05/23/1990 BK 86 PG 571 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-03 KIMBERLY S CHRISTY, ET UX 05/22/1990 BK 86 PG 567 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-04 CATHLEEN E CHRISTY THOMAS 05/22/1990 BK 86 PG 563 WY SUBLETTE T030 R112W SEC-0032 S/2, SW/4 59162-00 USA WYW-112560 07/01/1988 BK PG WY SUBLETTE T030N R112W SEC-0013 N/2, NE/4 AND SE/4, NE/4 T030N R112W SEC-0025 ALL T030N R112W SEC-0026 N/2 AND SE/4 T030N R112W SEC-0035 W/2 59195-00 USA WYW-121426 10/01/1990 BK 86 PG 718 WY SUBLETTE T031N R114W SEC-0012 E2 75002-00 USA WY-107066 01/01/1988 BK PG WY SUBLETTE T024N R114W SEC-0004 LOT 13 T024N R114W SEC-0008 NE, SW T024N R114W SEC-0017 N2, SW T024N R114W SEC-0020 N2, N2S2, S2SW 75004-00 USA WYW-122224 11/01/1990 BK PG WY LINCOLN T025N R112W SEC-0027 NENE, LOTS 1,2,6 75025-01 ELIZABETH D BENNETT 06/01/1990 BK291PR PG 311 WY LINCOLN T025N R112W SEC-0005 LOT 9(1.50), 13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-02 DORISE E HOUSLEY 10/24/1990 BK291PR PG 455 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-03 DENESE STACY 10/24/1990 BK291PR PG 398 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-04 ALVIN MARX, ET UX 10/24/1990 BK291PR PG 638 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-05 ERWIN MARX, ET UX 10/24/1990 BK291PR PG 453 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-06 DOROTHY J MCGINNIS ET VIR 10/24/1990 BK291PR PG 396 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-07 ELDON E MARX, ET UX 10/24/1990 BK291PR PG 394 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75026-00 RUBY D JETKOSKI, ET AL 06/13/1990 BK288PR PG 92 WY LINCOLN T025N R112W SEC-0027 LOTS 4(21.68), 5(36.03), 9(25.66), 10(39.93) AND ALL RIPARIAN RIGHTS TO SAID LOTS, S2SW, W2SE T025N R112W SEC-0028 LOTS 8(37.79), 9(14.07) 75034-00 USA WYW-109319 (ROW) 12/28/1988 BK PG WY LINCOLN T026N R111W SEC-0005 SESW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG. SWSE, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG T026N R111W SEC-0008 NENW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG 75035-01 BRUCE E JONES, ET UX 06/09/1990 BK288PR PG 86 WY SUBLETTE T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF NWNW OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE,LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY BOUNDARY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W, 1747; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING IN 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET FOR AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17' SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED, WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7' T025N R112W SEC-008 THOSE PORTIONS OF LOTS 3,6, AN 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 THAT PORTION OF THE SWNW AND NWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AND THAT PORTION OF THE SWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189; AND NORTH OF THE ACCESS DIRT ROAD LOT 2(17.72), 3(29.79), 6(37.38) AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0018 SENE, NESE AND THAT PORTION OF THE SESE LYING NORTH OF THE ACCESS ROAD T025N R112W SEC-0020 LOTS 2(29.19), 5(9.29), 9(29.12), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 LOTS 1,2 7 75035-2 CECIL R JONES, ET UX 06/09/1990 BK288PR PG 89 WY LINCOLN T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF NWN OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE, LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W. 1747'; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING N 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET OF AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17, SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED. WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7 T025N R112W SEC-0008 THOSE PORTIONS OF LOTS 3, 6, AND 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 LOTS 2(17.72), 3(29.79), 637.38, AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY # 189 ***SEE SECTION 0000 FOR ACREAGE*** T025N R112W SEC-0019 SESE, NESE AND THAT PORTION OF THE NENE LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189 AND BOUNDED ON THE N BY THAT CERTAIN LINE AS DEEDED IN BOOK 84 PHOTOSTATIC RECORDS AT PAGE 209 IN LINCOLN CO., WY T025N R112W SEC-0020 THAT PORTION OF THE W2W2 LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189, AND BOUNDED ON THE N BY THAT CERTAIN RIGHT OF WAY CENTER LINE AS DEEDED IN BOOK 884 PHOTOSTATIC RECORDS AT PG 209, LINCOLN CO., WY LOTS 2(29.19), 5(9.29), 9(29.12), 10(23.65), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 THAT PORTION OF THE NWNW LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189. LOTS 1, 2, 7 75044-00 USA WYW-82343 02/01/1983 BK PG WY SUBLETTE T030N R113W SEC-0005 N2SE, SWSE T030N R113W SEC-0007 NE 75045-00 ARDATH E HARMISON 11/08/1990 BK292 PG 594 WY LINCOLN T025N R112W SEC-0008 LOTS 4, 5, AND 8 T025N R112W SEC-0017 LOT 1 AND NWNE 75046-00 USA WYW-113668 12/01/1988 BK PG WY LINCOLN T025N R114W SEC-0001 LOTS 1-5, 8-11, 13-18, AND W/2 T025N R114W SEC-0002 N2, SE T025N R114W SEC-0003 ALL T025N R114W SEC-0034 TOWNSHIP 25 1/2M-RANGE 114W LOTS 1, 2, 3, 4 T025N R114W SEC-0035 TOWNSHIP 25 1/2N-RANGE 114W LOTS 3, 4 75111-00 USA WYW-125000 10/01/1991 BK 87 PG 720 WY SUBLETTE T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 75115-00 USA W-26615 12/01/1970 BK PG WY SUBLETTE T028N R114W SEC-0005 SWSE E - RECORD TITLE 75121-00 USA WY-43217 02/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0008 LOT 1 75122-00 USA WY-6317 07/01/1967 BK PG WY SUBLETTE T028N R114W SEC-0005 LOT 11 74127-00 USA WY-320214 11/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0034 N2, N2S2, LOTS 1-4 T029N R114W SEC-0035 N2, N2S2, LOTS 1-4 75171-00 STATE OF WYOMING 89-00105 02/02/1989 BK PG WY LINCOLN T026N R113W SEC-0022 S2SW 75173-00 USA WYW-126688 05/01/1992 BK PG WY LINCOLN T024N R114W SEC-0007 NE T025N R114W SEC-0008 NW T024N R114W SEC-0021 SW 50029-00 USA EV-26176-B 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0032 NENE 50031-00 USA W-21127 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0027 NW4, S2 T030N R113W SEC-0034 NE 50033-00 USA W-21128 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 SW 50188-00 USA W-05991 06/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0003 LOTS 1(40.50), 2(39.99), 3(39.95), 4(39.90) T030N R113W SEC-0004 LOTS 1(39.89) 2(39.90) 50271-00 USA W-044101 10/01/1950 BK PG WY LINCOLN T026N R113W SEC-0017 E2 T026N R113W SEC-0020 N2 T026N R113W SEC-0021 N2 57542-00 USA WYW-113640 12/01/1988 BK 82 PG 160 WY SUBLETTE T027N R111W SEC-0012 N/2, E/2SW, SE T027N R111W SEC-0013 N/2 T027N R111W SEC-0024 N/2, SW 57575-00 USA WYW-114336 03/01/1979 BK PG WY SUBLETTE T031N R113W SEC-0030 SE, S2NE 57607-00 MICKELSON GORDON ET UX 11/01/1988 BK 82 PG 289 WY SUBLETTE T031N R113W SEC-0019 S2NE 58006-00 USA WYW-116386 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0028 NESW T031N R113W SEC-0033 SENE 58083-00 ALSADE, LTD. 09/09/1989 BK PG WY SUBLETTE T031N R113W SEC-0029 EXISTING ACCESS ROAD LOCATED; SWSE,NWSW,SWNW EITHER SIDE OF CENTERLINE, FOR THE PURPOSE OF INGRESS AND EGRESS ONLY. 58187-00 USA W-117895 11/01/1989 BK 84 PG 597 WY SUBLETTE T031N R113W SEC-0020 NESW, S/2SW, N/2SE, SWSE T031N R113W SEC-0021 SWNW, NESW, W/2SE T031N R113W SEC-0028 N/2NW 75048-00 USA W-107067 02/01/1988 BK PG WY SUBLETTE T025N R114W SEC-0024 LOTS 1-12, W/2 75256-00 USA EV-023768 12/01/1947 BK 31 PG 429 WY SUBLETTE T025N R113W SEC-0020 SWSW 75257-00 USA EV-022879 07/01/1947 BK 30 PG 545 WY SUBLETTE T028N R113W SEC-0019 LOTS 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17 75258-00 USA EV-023328 10/01/1948 BK 33 PG 637 WY SUBLETTE T028N R113W SEC-0030 N2NE 75259-00 USA EV-023553 06/01/1948 BK 33 PG 193 WY SUBLETTE T028N R113W SEC-0030 S2NE 75260-00 USA WY-01495 02/01/1950 BK 34 PG 83 WY SUBLETTE T028N R113W SEC-0018 LOTS 11, 12,13, 14, 15, 16, 17, 18, W2SE 75237-00 ST WY-86-00117 02/02/1986 BK236 PG 470 WY LINCOLN T026N R112W SEC-0016 NW, NWNE, S2NE, S2
PART III TO EXHIBIT A (CONVEYANCE) ENRON OIL & GAS COMPANY WELL LISTING DENVER EXHIBIT A GROUP A
WORKING REVENUE WORKING REVENUE INTEREST INTEREST INTEREST INTEREST WELL NAME WELL NUMBER ST COUNTY BPO BPO APO APO BNG 110-09 F CW 00239-70-00-1 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 9-26N-113W ORIGINAL WELLS BNG 110-09 M CW 00239-70-00-2 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SENW 9-26N-113W ORIGINAL WELLS BNG 111-04 F 00239-80-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 4-26N-113W ORIGINAL WELLS BNG 111-04 M 00239-80-00-2 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SWNW 4-26N-113W ORIGINAL WELLS BNG 34-04 F LW 00243-40-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 34-04 M 00243-40-00-2 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 39-04 00243-80-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESE 4-26N-113W ORIGINAL WELLS BNG 42-04 00244-40-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 45-04 00244-70-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENE 4-26N-113W ORIGINAL WELLS BNG 83-09 LW *00249-30-00-1 WYLINCOLN 1.0000000 .8330000 1.0000000 .8330000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 9-26N-113W ORIGINAL WELLS BNG 83-09 LW *00249-30-00-2 WYLINCOLN 1.0000000 .8330000 1.0000000 .8330000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NENE 9-26N-113W ORIGINAL WELLS CDR CRK 15-05 CW 01981-80-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 815' FNL, 2415' FWL 5-26N-113W LOT 3 ORIGINAL WELLS CDR CRK 16-05 CW 01981-90-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1950' FNL & 1800' FEL 5-26N-113W (LOT 7) ORIGINAL WELLS CDR CRK 17-05 CW 02139-50-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 796' FNL, 900' FEL 5-26N-113W (LOT 1) ORIGINAL WELLS COW HOLLOW 21 LW 02187-50-00-1 WY LINCOLN .0362000 .0256990 .0250000 .0209380 OPERATOR: BANNON ENERGY INC. FORMATION: FRONTIER DESCRIPTION: SENE8-22N-112W 1780' FNL & 660' FEL ORIGINAL WELLS E ST CAN 20-13 CW 00163-10-00-1 WY LINCOLN 1.0000000 .8470250 1.0000000 .8470250 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1664' FNL, 1120' FEL 13-26N-112W LOT 2, SENE ORIGINAL WELLS ELB 10-04 PW 00769-00-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 4-26N-112W ORIGINAL WELLS ELB 11-05 PW 00769-10-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 5-26N-112W ORIGINAL WELLS ELB 23-05 PW 00770-70-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 5-26N-112W ORIGINAL WELLS ELB 24-05 PW 00770-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 5-26N-112W ORIGINAL WELLS ELB 34-08 PW 00771-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 8-26N-112W ORIGINAL WELLS ELB 35-05 PW 00771-90-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESW 5-26N-112W ORIGINAL WELLS ELB 36-08 PW 00772-00-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 8-26N-112W ORIGINAL WELLS ELB 37-04 PW 00772-10-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 4-26N-112W ORIGINAL WELLS ELB 59-04D PW 02147-50-00-1 WY LINCOLN .5137380 .4433424 .5137380 .4433424 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 738' FSL, 936' FEL 4-26N-112W SESE ORIGINAL WELLS ELB 61-05 PW 01912-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 5-26N-112W ORIGINAL WELLS ELB 62-05 PW 00151-80-00-1 WY LINCOLN 1.0000000 .8656687 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 14 5-26N-112W ORIGINAL WELLS ELB 63-08 PW 00151-90-00-1 WY LINCOLN 1.0000000 .8646549 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 14 8-26N-112W ORIGINAL WELLS ELB 9-08 PW 00773-40-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 8 8-26N-112W ORIGINAL WELLS ESU 1-21 PW *00779-20-00-1 WY LINCOLN .9361700 .7559590 .9361700 .7559590 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 21-23N-112W ORIGINAL WELLS FONTENELLE RES 1-22 02003-70-00-1 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1495' FNL, 1120' FEL 22-25N-112W SENE ORIGINAL WELLS FONTENELLE 22-22B *00913-00-00-1 WY LINCOLN .0000000 .0045000 .0720000 .0594000 OPERATOR: PG&E RESOURCES COMPANY FORMATION: FRONTIER DESCRIPTION: SENW-22-26N-112W (STEAD CANYON PROSPECT ORIGINAL WELLS GRB B 1-1(BAX) PW 00144-00-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1366' FNL, 1664' FWL 1-26N-113W LOT 37, SENW ORIGINAL WELLS GRB B 10-12(BAX) PW 01975-80-00-1 WY LINCOLN 1.0000000 .8551525 1.0000000 .8551525 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 234' FNL, 2734' FEL 12-26N-113W LOT 37, NENW ORIGINAL WELLS GRB B 11-30 LW 02139-60-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 560' FWL, 1900' FNL 30-27N-112W LOT 2, SWNW ORIGINAL WELLS GRB B 13-30 LW 02139-70-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 200' FSL & 1200' FWL, SESW, 30-27N-112W ORIGINAL WELLS GRB B 14-31 LW 02139-80-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 925' FNL & 120 FWL, LOT 3 (NWNW), 31-27N-112W ORIGINAL WELLS GRB B 7-1(BAX) PW 01975-60-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 560' FEL & 2224' FNL (LOT 37) 1-26N-113W ORIGINAL WELLS GRB B 9-1(BAX) PW 01975-70-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2785' FEL & 3610' FNL, LOT 37, (SENW), 1-26N-113W ORIGINAL WELLS GRB CP-1 PW 00945-50-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 7-26N-112W ORIGINAL WELLS GRB CP-2 PW 00945-60-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 18-26N-112W ORIGINAL WELLS GRB CP-500945-70-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 6-26N-112W ORIGINAL WELLS GRB T 19-03 PW *00946-60-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: LOT 8 3-26N-113W ORIGINAL WELLS GRB T 22-03 PW *00946-90-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: LOT 9 3-26N-113W ORIGINAL WELLS GRB T 23-03 PW *00947-00-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 3-26N-113W, NESE ORIGINAL WELLS GRB T 31-02 PW *00947-80-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 2-26N-113W, NWNW ORIGINAL WELLS GRB T 34-03 PW *00948-10-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 3-26N-113W, SESE ORIGINAL WELLS GRB T 49-10 PW *00949-20-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 10-26N-113W, NENE ORIGINAL WELLS GRB T 50-10 LW *00949-50-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 10-26N-113W, SENE ORIGINAL WELLS GRB 12-07 00952-10-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 7-26N-112W ORIGINAL WELLS GRB 136-18 F(T) PW 02139-90-00-1 WY LINCOLN .9198070 .6798948 .9198070 .6798489 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 334' FNL & 1910' FWL, 18-26N-112W, NENW ORIGINAL WELLS GRB 136-7 F(PROP) 00159-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 334' FNL & 1910' FWL, 18-26N-112W, NENW ORIGINAL WELLS GRB 137-18 F PW 02140-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2600' FNL & 150' FWL, LOT 2(SWNW) 18-26N-112W ORIGINAL WELLS GRB 138-18 F(C) PW 02140-10-00-2 WY LINCOLN .9180700 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1642' FEL & 2058' FNL SWNE 18-26N-112W ORIGINAL WELLS GRB 138-18 F(T) PW 02140-10-00-1 WY LINCOLN .9180700 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1642' FEL & 2058' FNL, SWNE, 18-26N-112W ORIGINAL WELLS GRB 141-01 BR PW 00158-40-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 550' FNL & 1500' FEL (NWNE) SEC 1-26N-113W ORIGINAL WELLS GRB 141-01 F PW 00158-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 550' FNL & 1500' FEL (NWNE) SEC 1-26N-113W ORIGINAL WELLS GRB 148-2 BR PW 00158-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER/35% ALLOCATION DESCRIPTION: 400' FSL & 2350' FWL, 2-26N-113W, SESW ORIGINAL WELLS GRB 148-2 F PW 00158-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: ENRON OIL & GAS FORMATION: FRONTIER A-B / 65% ALLOC DESCRIPTION: 400' FSL & 2350' FWL, 2-26N-113W, SESW ORIGINAL WELLS GRB 149-10 BR LW 01985-40-00-2 WY LINCOLN 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 1770' FNL & 358' FEL, SEC. 10-26N-113W, (SENE) ORIGINAL WELLS GRB 149-10 F PW 01985-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1770' FNL & 358' FEL, SEC. 10-26N-113W, (SENE) ORIGINAL WELLS GRB 150-10 PW 02006-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1790' FSL & 500' FEL, NESE, 10-26N-113W ORIGINAL WELLS GRB 159-13 PW 01985-50-00-1 WY LINCOLN .9198070 .7792080 .9198070 .7792080 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 800' FWL & 2100' FNL, SWNW, 13-26N-113W ORIGINAL WELLS GRB 160-14 PW 01985-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2398' FNL & 2330' FEL, SWNE, 14-26N-113W ORIGINAL WELLS GRB 166-18 PW 00952-60-00-1 WY LINCOLN 1.0000000 .7211968 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 497' FWL & 635' FSL, SEC. 18-26N-112W, (LOT 4) ORIGINAL WELLS GRB 17-11 BR PW 00952-70-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWSE 11-26N-113W ORIGINAL WELLS GRB 17-11 F PW 00952-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 11-26N-113W ORIGINAL WELLS GRB 173-15 F PW 02140-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 400' FEL & 1570' FNL, SENE, 15-26N-113W ORIGINAL WELLS GRB 175-10 PW 02006-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 50' FSL & 50' FEL, 10-26N-113W, SESE ORIGINAL WELLS GRB 18-01 BR PW 00952-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENW 1-26N-113W ORIGINAL WELLS GRB 18-01 F PW 00952-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 1-26N-113W ORIGINAL WELLS GRB 188-22 F PW 02140-30-00-1 WY LINCOLN 1.0000000 .8472298 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 590' FNL & 600' FEL, LOT 1(NENE) 22-26N-113W ORIGINAL WELLS GRB 2-12 PW 00953-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 12-26N-113W ORIGINAL WELLS GRB 23-02 BR PW 00953-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWNW 2-26N-113W ORIGINAL WELLS GRB 23-02 F PW 00953-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 2-26N-113W ORIGINAL WELLS GRB 24-02 PW 00953-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 2-26N-113W ORIGINAL WELLS GRB 25-02 F PW 00953-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 2-26N-113W ORIGINAL WELLS GRB 27-14 PW 00953-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 14-26N-113W ORIGINAL WELLS GRB 30-15 PW 00954-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 15-26N-113W ORIGINAL WELLS GRB 30-15 BAXTER LW 00954-40-00-2 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESE 15-26N-113W ORIGINAL WELLS GRB 34-06 PW 00954-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 6-26N-112W ORIGINAL WELLS GRB 4-13 PW 00955-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 13-26N-113W ORIGINAL WELLS GRB 42-13 PW 00955-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 13-26N-113W ORIGINAL WELLS GRB 43-11 F PW 00955-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 11-26N-113W ORIGINAL WELLS GRB 43-11 M PW 00955-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNW 11-26N-113W ORIGINAL WELLS GRB 44-14 PW 00955-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 14-26N-113W ORIGINAL WELLS GRB 44-14 BAXTER LW 00955-70-00-2 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENW 14-26N-113W ORIGINAL WELLS GRB 45-12 PW 00955-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 12-26N-113W ORIGINAL WELLS GRB 46-01 PW 00955-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 1-26N-113W ORIGINAL WELLS GRB 47-02 PW 00956-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 2-26N-113W ORIGINAL WELLS GRB 51-01 PW 00956-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 1-26N-113W ORIGINAL WELLS GRB 53-23 LW 00956-60-00-2 WY LINCOLN 1.0000000 .8350000 1.0000000 .8350000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNW 23-26N-113W ORIGINAL WELLS GRB 53-23 PW 00956-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 23-26N-113W ORIGINAL WELLS GRB 55-01 BR PW 00956-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 1-26N-113W ORIGINAL WELLS GRB 55-01 F PW 00956-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 1-26N-113W ORIGINAL WELLS GRB 58-18 PW 00957-00-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 18-26N-112W ORIGINAL WELLS GRB 64-11 BR PW 00957-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWNE 11-26N-113W ORIGINAL WELLS GRB 64-11 F PW 00957-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 11-26N-113W ORIGINAL WELLS GRB 65-14 PW 00957-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 14-26N-113W ORIGINAL WELLS GRB 71-06 PW 00958-70-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 6-26N-112W ORIGINAL WELLS GRB 76-14 BR PW 00959-20-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 14-26N-113W ORIGINAL WELLS GRB 76-14 F PW 00959-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 14-26N-113W ORIGINAL WELLS GRB 77-13 PW 00959-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 13-26N-113W ORIGINAL WELLS GRB 78-13 PW 00959-40-00-1 WY LINCOLN 1.0000000 .8461968 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 13-26N-113W ORIGINAL WELLS GRB 79-12(BAX) PW 00959-50-00-3 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1320' FNL & 1320' FEL, NENE, 12-26N-113W ORIGINAL WELLS GRB 79-12 BR LW 00959-50-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 12-26N-113W ORIGINAL WELLS GRB 79-12 F PW 00959-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1320' FNL & 1320' FEL, SEC. 12-26N-113W, (NENE) ORIGINAL WELLS GRB 80-07 BR LW 00959-70-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENW 7-26N-112W ORIGINAL WELLS GRB 80-07 F PW 00959-70-00-1 WY LINCOLN .9198070 .7792040 .9898070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 7-26N-112W ORIGINAL WELLS GRB 82-6 PW 00959-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 800' FWL & 2200' FNL, SENW, 6-26N-112W ORIGINAL WELLS GRB 83-07 BR LW 00960-00-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSW 7-26N-112W ORIGINAL WELLS GRB 83-07 F PW 00960-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 7-26N-112W ORIGINAL WELLS GRB 84-18 PW 00960-10-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 18-26N-112W ORIGINAL WELLS GRB 85-12 PW 00960-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSW 12-26N-113W ORIGINAL WELLS GRB 87-11 PW 00960-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 11-26N-113W ORIGINAL WELLS HANSON FEDERAL 40-06 *00984-30-00-1 WY LINCOLN .5000000 .4075000 .5000000 .4075000 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 2882' FNL, & 968' FEL, SEC. 6-26N-11W, (NESE) ORIGINAL WELLS HYRUM DITCH 11X26 CW *01011-50-00-1 WY LINCOLN .0000000 .0110690 .0000000 .0110690 OPERATOR: FMC CORPORATION FORMATION: FRONTIER DESCRIPTION: PT RE-SURV LOT 44 & 45, LOTS 3 & 4-26&27-T26N-113W ORIGINAL WELLS HYRUM DITCH 31X26 CW *00011-60-00-1 WY LINCOLN .0000000 .0058330 .0000000 .0000000 OPERATOR: FMC CORPORATION FORMATION: FRONTIER DESCRIPTION: LOT 7, 8, PT LOTS 41 & 43-26-T26N-R113W ORIGINAL WELLS LANSDALE FED 10-8 CW 01932-70-00-1 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LANSDALE FED 10-8 CW 01932-70-00-2 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 OPERATOR: EOG FORMATION: 2ND FRONTIER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LANSDALE FED 10-8 CW 01932-70-00-3 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LARSON 1-17 LW *01031-50-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 17-26N-112W ORIGINAL WELLS MCGINNIS 1-17 LW *01071-70-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 17-26N-112W ORIGINAL WELLS OPAL 4-21 LW *00472-80-00-1 WY LINCOLN 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 21-22N-112W ORIGINAL WELLS SHB 1-08(F) CW 00519-20-00-2 WY LINCOLN .9500000 .7748750 .9500000 .7748750 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1308 FNL 1388 FEL NWNE-8-26N-113W (HOGBACK PROSPECT) ORIGINAL WELLS SHB34-08 CW *00615-10-00-1 WY LINCOLN .2500000 .2025000 .2500000 .2025000 OPERATOR: MOBIL OIL CORPORATION FORMATION: BEAR RIVER/MUDDY DESCRIPTION: E2-8-26N-113W ORIGINAL WELLS SHB 12-04 CW 00515-60-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 12 4-26N-113W ORIGINAL WELLS SHB 13-08A CW 00515-70-00-1 WY LINCOLN .9459459 .7714898 .9500000 .7748750 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NW SE 8-26N-113W ORIGINAL WELLS SHB 15-04(BAX) CW 00515-80-00-2 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 15-04(FRONT) CW 00515-80-00-3 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 15-04(MUD) CW 00515-80-00-1 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 21-04 00515-90-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 10 4-26N-113W ORIGINAL WELLS SHB 21-04 00515-90-00-2 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: LOT 10 4-26N-113W ORIGINAL WELLS SHB 3-16 F 00519-30-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 16-26N-113W ORIGINAL WELLS SHB 3-16 M 00519-30-00-2 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SWNW 16-26N-113W ORIGINAL WELLS SHB 4-09 F 00519-50-00-2 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 9-26N-113W ORIGINAL WELLS SHB 4-09 M 00519-50-00-1 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWSW 9-26N-113W ORIGINAL WELLS SHB 5-16 LW 00519-60-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SW 16-26N-113W ORIGINAL WELLS SHB 6-16 00519-70-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 16-26N-113W ORIGINAL WELLS SLB 1-04 (CW) 00528-30-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: LOT 11 4-26N-113W ORIGINAL WELLS SLB 1-04 (CW) 00528-30-00-2 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 11 4-26N-113W ORIGINAL WELLS SPR CRK 7-14 LW P&A 00570-20-00-1 WY LINCOLN .0000000 .0000000 .0000000 .0000000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 14-26N-112W ORIGINAL WELLS ST CAN 1-15 00586-30-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NENE 15-26N-112W ORIGINAL WELLS ST CAN 19-13 LW *00587-10-00-2 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1515' FSL & 3455' FWL, NWSE, 13-26N-112W ORIGINAL WELLS ST CAN 19-13 PW 00587-10-00-1 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: FRONTIER B DESCRIPTION: 1515' FSL & 3455' FWL, NWSE, 13-26N-112W ORIGINAL WELLS ST CAN 3-13 LW 00587-30-00-2 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2240' FNL & 1104" FEL, SEC. 13-26N-112W, (SESW) ORIGINAL WELLS ST CAN 3-13 PW 00587-30-00-1 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: FRONTIER B DESCRIPTION: SESW 13-26N-112W ORIGINAL WELLS ST CAN 5-14BAX LW 00587-50-00-2 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: BAXTER(RECOMPLETION) DESCRIPTION: 50' FNL & 650' FEL, SEC. 14, 26N, 112W, (NE NE) ORIGINAL WELLS ST CAN 5-14 LW(TA) 00587-50-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 50' FNL & 650' FEL, SEC. 14-26N-112W, (NENE) ORIGINAL WELLS ST CAN 6-10 00587-60-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NWSE 10-26N-112W ORIGINAL WELLS ST CAN 7-10 00587-70-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: SWSW 10-26N-112W ORIGINAL WELLS ST CAN 8-11(BAX) PW 00587-80-00-3 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2496' FSL & 429' FWL 11-26N-112W NWSW ORIGINAL WELLS ST CAN 8-11 F 00587-80-00-2 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NWSW 11-26N-112W ORIGINAL WELLS ST CAN 9-11 LW 00588-00-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1350' FWL & 950' FNL, 11-26N-112W, (N2NW) ORIGINAL WELLS W ST CAN 12-9 LW 00817-90-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1203' FNL & 1414' FWL, SEC. 9-26N-112W, (NWNW) ORIGINAL WELLS W ST CAN 13-09 LW 01989-30-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1127' FSL & 769' FWL, SEC. 9-26N-112W, (SWSW) ORIGINAL WELLS W ST CAN 14-9 00149-60-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2130' FNL & 1450' FEL, SEC. 9-26N-112W, (SWNE) ORIGINAL WELLS W ST CAN 15-09 LW 01989-40-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: 2ND FRONTIER DESCRIPTION: 1538' FSL & 1920' FEL, SEC 9-26N-112W, (NWSE) ORIGINAL WELLS W ST CAN 17-9D LW *02140-90-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1225' FNL, 1197' FWL 9-26N-112W NWNW ORIGINAL WELLS W ST CAN 18-17 LW 02134-80-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 17-26N-112W ORIGINAL WELLS W ST CAN 20-9D LW 02141-00-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2500' FSL, 1900' FWL 9-26N-112W NESW ORIGINAL WELLS WEST SWAN 1-24 CW 02130-50-00-1 WY LINCOLN 1.0000000 .8371750 1.0000000 .8371750 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 553' FEL, 953' FNL 24-25N-112W LOT 1 ORIGINAL WELLS WEST SWAN 2-25 LW 02138-00-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 550'FEL, 2180'FSL 25-25N-112W LOT 3 ORIGINAL WELLS WEST SWAN 3-25 LW 02141-10-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2155' FWL & 2109' FSL 25-25N-112W NESW ORIGINAL WELLS WILLOW CREEK 1-03 PW *00831-10-00-1 WY LINCOLN .7500000 .6333050 .7500000 .6333605 OPERATOR: EOG FORMATION: FORT UNION DESCRIPTION: NWNW 3-24N-114W ORIGINAL WELLS AMOCO AG-1/FED 40-18 *00110-90-00-1 WY SUBLETTE .0000000 .0026760 .0446015 .0347892 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: SE 18-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS AMOCO AH-1/FED 20-19 *00111-00-00-1 WY SUBLETTE .0000000 .0055980 .0711640 .0561719 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: NENE 19-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS AMOCO AJ-1/FED.20-18 *00110-80-00-1 WY SUBLETTE .0000000 .0026760 .0446015 .0347892 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: NE 18-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS B & H 1-01 LW 00730-00-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 01-27N-114W ORIGINAL WELLS B 1A-22 LW *00730-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 22-29N-113W ORIGINAL WELLS B 11TC-14LW (TA) 00200-00-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 14-29N-113W ORIGINAL WELLS B 15A-11 LW *00200-10-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWSW 11-29N-113W, ORIGINAL WELLS B 16-15 LW *00200-20-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 15-29N-113W ORIGINAL WELLS B 18-02 LW *00200-40-00-1 WY SUBLETTE 1.0000000 .7912500 1.0000000 .7912500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSW 2-29N-113W ORIGINAL WELLS B 22-25 LW *00200-60-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 25-29N-113W ORIGINAL WELLS B 26-14 LW&*00200-70-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 14-29N-113W ORIGINAL WELLS B 3-23LW *00201-00-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 23-29N-113W ORIGINAL WELLS B 30-25 LW *00201-10-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENE 25-29N-113W ORIGINAL WELLS B 33-10 LW *00201-40-00-1 WY SUBLETTE 1.0000000 .7412500 1.0000000 .7412500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 10-29N-113W ORIGINAL WELLS B 36-25 PW *00201-50-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESW 25-29N-113W ORIGINAL WELLS B 39-11 LW *00201-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 11-29N-113W ORIGINAL WELLS B 4-26 LW *00201-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NESW 26-29N-113W ORIGINAL WELLS B 43-24 LW *00201-90-00-1 WY SUBLETTE 1.0000000 .8475000 1.0000000 .8475000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 24-29N-113W ORIGINAL WELLS B 44-25 00202-00-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 25-29N-113W ORIGINAL WELLS B 45-02 LW *00202-10-00-1 WY SUBLETTE 1.0000000 .7912500 1.0000000 .7912500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 2-29N-113W ORIGINAL WELLS B 5-35 LW *00202-40-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 35-29N-113W ORIGINAL WELLS B 5A-35 LW *00202-50-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 35-29N-113W ORIGINAL WELLS B 57-23 PW *00202-70-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESE 23-29N-113W ORIGINAL WELLS B 62-14 LW 00203-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-29N-113W ORIGINAL WELLS B 63-26 00203-10-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 26-29N-113W ORIGINAL WELLS B 65-23LW (TA) *00203-20-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNE 23-29N-113W ORIGINAL WELLS B 68-14 LW *00203-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-29N-113W ORIGINAL WELLS B 69 TC-0300203-40-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: TRANSITION (TUBING) DESCRIPTION: SWNE 3-29N-113W ORIGINAL WELLS B 69 TC-0300203-40-00-2 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: ALMY (CASING) DESCRIPTION: SWNE 3-29N-113W ORIGINAL WELLS B 70-14LW (TA)&*00203-50-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 14-29N-113W ORIGINAL WELLS - B 71-14LW (TA)&*00203-60-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 14-29N-113W ORIGINAL WELLS B 81-24LW (TA) *00203-70-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNW 24-29N-113W ORIGINAL WELLS B 82-24 LW *00203-80-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 24-29N-113W ORIGINAL WELLS B 9-14LW&*00204-10-00-2 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 875' FNL & 780' FWL, SEC. 14-29N-113W, (NWNW) ORIGINAL WELLS - B 9A-14 LW00204-10-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNW 14-29N-113W ORIGINAL WELLS BESS CANYON 5-3501988-70-00-1 WY SUBLETTE 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 760' FNL & 460' FEL, SEC. 35-27N-112W, (NENE) ORIGINAL WELLS BIG PINEY LABARGE MV*99999-99-99-NWY SUBLETTE 1.0000000 .8571348 1.0000000 .8571348 OPERATOR: EOG FORMATION: MESV TRANS/M SAND DESCRIPTION: MESAVERDE TRANSITION/M SAND (TIP TOP SHALLOW UNIT) ORIGINAL WELLS BIRD CANYON FED 20-6*00108-80-00-1WY SUBLETTE .2121756 .1644361 .2121756 .1644361 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: NE 6-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS BIRD STATE 1-16 LW*00229-60-00-1WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 16-27N-112W ORIGINAL WELLS BIRD STATE 2-16 LW*00229-70-00-1WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 16-27N-112W ORIGINAL WELLS BIRD STATE 3-16 LW&*00229-80-00-1WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NW 16-27N-112W ORIGINAL WELLS BNG70-28LW *00247-80-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 1-28LW *00238-60-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: MEASAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 101-33 PW &*00238-80-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS BNG 102-33 PW &*00238-90-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS - BNG 104-33 PW &*00239-10-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, NWSW ORIGINAL WELLS BNG 105-04 PW &*00239-20-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NENW ORIGINAL WELLS BNG 106-04 WIW&*00239-30-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: NWNW 4-27N-113W ORIGINAL WELLS BNG 107-32 PW *00239-40-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, SESE ORIGINAL WELLS BNG 11-23 LW00239-60-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 23-28N-113W ORIGINAL WELLS - BNG 112-21 PW *00239-90-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 114-28 PW *00240-10-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NWNW ORIGINAL WELLS BNG 115-21 PW *00240-20-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, NESW ORIGINAL WELLS BNG 116-28 PW *02007-90-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 118-20 PW *00240-50-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 20-28N-113W, SESW ORIGINAL WELLS BNG 15-32 PW 00241-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 32-28N-113W, NESE ORIGINAL WELLS BNG 16-05 PW 00241-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, NENE ORIGINAL WELLS BNG 17-05 PW 00241-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, SESE ORIGINAL WELLS BNG 18-17 PW 00241-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, SWNE ORIGINAL WELLS BNG 19-08 PW 00241-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NWSW ORIGINAL WELLS BNG 2-28LW *00241-90-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NWSE ORIGINAL WELLS BNG 20-32 LW *00242-00-00-1 WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 32-28N-113W ORIGINAL WELLS - BNG 21-20 PW 00242-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, NENE ORIGINAL WELLS BNG 22-05 PW 00242-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, SWSW ORIGINAL WELLS BNG 25-09 PW 00242-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SESW ORIGINAL WELLS BNG 26-21 PW 00242-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENE ORIGINAL WELLS BNG 27-04 PW 00242-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 4-27N-113W, SESW ORIGINAL WELLS BNG 28-33 PW 00242-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SESE ORIGINAL WELLS BNG 29-33 PW 00242-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS - BNG 30-28 FVPU00243-10-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS - BNG 30-28 MVPU00243-10-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS BNG 31-21 LW00243-20-00-1 WY SUBLETTE .5000000 .4375000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENW 21-27N-112W ORIGINAL WELLS BNG 36-16 PW 00243-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SENE ORIGINAL WELLS BNG 37-33 00243-60-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NESE, SEC. 33-27N-113W ORIGINAL WELLS BNG 37-33 LW00243-60-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWSE 33-27N-113W ORIGINAL WELLS BNG 37-33 (BAX) LW00243-60-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2640' FNL & 1330' FEL 33-27N-113W NESE ORIGINAL WELLS - BNG 37-33 (TGS) LW00243-60-00-4WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWSE 33-27N-113W ORIGINAL WELLS BNG 38-09 PW 00243-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SWNW ORIGINAL WELLS BNG 40-32 PW &*00244-20-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, NESE ORIGINAL WELLS BNG 41-28 PW *00244-30-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 43-28VPU00244-50-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS BNG 46-28 PW *00244-80-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRANS/M SAND DESCRIPTION: SEC. 28-28N-113W, NWNW ORIGINAL WELLS BNG 47C-33 WIW&*00245-00-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWSW 33-28N-113W ORIGINAL WELLS -BNG 49-33 PW 00245-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SESW ORIGINAL WELLS BNG 5-08 PW 00245-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, SESE ORIGINAL WELLS BNG 50-16 PW 00245-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SWNW ORIGINAL WELLS BNG 50-16 (BAX) LW00245-50-00-2 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1000' FWL & 1425' FNL, 16-27N-113WSWNW ORIGINAL WELLS BNG 51-04 PW 00245-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 4-27N-113W, SENW ORIGINAL WELLS BNG 53-29 PW *00245-80-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 29-28N-113W, NENE ORIGINAL WELLS BNG 54-28 PW *00245-90-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 55-33 PW &*00010-00-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS BNG 56-20 PW *00246-10-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 20-28N-113W, SWSE ORIGINAL WELLS BNG 59-32WIW&*00246-40-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SENE 32-28N-113W ORIGINAL WELLS BNG 6-33LW *00246-50-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 33-28N-113W ORIGINAL WELLS - BNG 63-29 PW *00246-80-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNE ORIGINAL WELLS BNG 69-33WIW&*00247-30-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSW 33-28N-113W ORIGINAL WELLS BNG 71-32WIW&*00247-90-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SESE 32-28N-113W ORIGINAL WELLS - BNG 72-33WIW&*00248-10-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWNW 33-28N-113W ORIGINAL WELLS BNG 75-28 PW*00248-30-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRANS/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 76-21 PW *00248-40-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 77-21 PW *00248-50-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 21-28N-113W, NWSW ORIGINAL WELLS BNG 80-32 PW &*00249-00-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, SESE ORIGINAL WELLS BNG 81-08 PW 00249-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NESE ORIGINAL WELLS BNG 82-28 LW *00249-20-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SEC. 28-28N-113W, SENW ORIGINAL WELLS - BNG 84-04 PW &*00249-40-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NENW ORIGINAL WELLS BNG 86-04 PW &*00249-50-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, SENW ORIGINAL WELLS BNG 88-04 PW &*00249-60-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NESW ORIGINAL WELLS BNG 90TC-04WIW&*00249-90-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWNW 4-27N-113W ORIGINAL WELLS BNG 92-28 B 00250-00-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 860' FSL & 2700' FEL28-27N-113WSESW ORIGINAL WELLS BNG 92-28 F 00250-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESW 28-27N-113W ORIGINAL WELLS - BNG 92-28 M 00250-00-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESW 28-27N-113W ORIGINAL WELLS - BNG 93-20 LW *00250-10-00-1WY SUBLETTE .5000000 .4375000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 20-27N-112W ORIGINAL WELLS BNG 94A-21 PW *02018-00-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 97-21 PW *00250-60-00-1WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, NWSW ORIGINAL WELLS - BNG 98-04 PW &*00250-70-00-1WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NWNW ORIGINAL WELLS BNG 99-04WIW&*00250-80-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: NESW 4-27N-113W ORIGINAL WELLS BPMV 15-12 WIW PW*00265-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 1-11A PW &*00261-00-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SWSE) ORIGINAL WELLS - BPMV 1-11A (TRAN)PW&*00261-00-00-2 WY SUBLETTE.5487000 .4632169 .5487000 .4632169 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SWSE) ORIGINAL WELLS BPMV 1-58 PW &*00261-10-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SWSE) ORIGINAL WELLS BPMV 1-59 PW &*00261-20-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (NWNE) ORIGINAL WELLS BPMV 1-62 PW &*00261-30-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SESW) ORIGINAL WELLS BPMV 1-62 (TRANS) PW&*00261-30-00-2WY SUBLETTE .5487000 .4632169 .5487000 .4632169 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SESW) ORIGINAL WELLS BPMV 1-64 PW &*00261-40-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SENW) ORIGINAL WELLS BPMV 1-64 (TRANS) PW&*00261-40-00-2WY SUBLETTE .5487000 .4632169 .5487000 .4632169 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SENW) ORIGINAL WELLS - BPMV 1-65 PW &*00261-50-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SWNE) ORIGINAL WELLS BPMV 1-66 PW &*00261-60-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (NWSE) ORIGINAL WELLS BPMV 1-67 PW &*00261-70-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (NESW) ORIGINAL WELLS BPMV 1-83 PW &*00261-80-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (NESW) ORIGINAL WELLS BPMV 1-84 WIW PW&*00261-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SESE) ORIGINAL WELLS BPMV 10-01WIW PW *00262-10-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWNW) ORIGINAL WELLS BPMV 11-56 PW *00262-20-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 26-29N-113W (NENE) ORIGINAL WELLS - BPMV 13-01 PW *00262-40-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-34 PW *00262-60-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-49 PW *00262-70-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-53 WIW PW TA*00263-00-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (NWSW) ORIGINAL WELLS BPMV 13-86 WIWPW *00263-20-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (NWSW) ORIGINAL WELLS BPMV 14-01 PW *00263-30-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS - BPMV 14-02 PW *00263-40-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS - BPMV 14-33 (WIW)PW*00263-50-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-34 PW*00263-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-36 WIWPW*00263-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-38 PW*00263-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SWNE) ORIGINAL WELLS BPMV 14-42 (WIW)PW*00264-00-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS BPMV 14-43 PW*00264-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 14-48 PW*00264-40-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS - BPMV 14-49 PW*00264-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS -BPMV 14-51 WIWPW TA*00264-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 14-74 PW &*00264-80-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (SENW) ORIGINAL WELLS BPMV 14-75 PW*00264-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SWNE) ORIGINAL WELLS BPMV 14-76 WIWPW*00265-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 15-02 PW*00266-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSW) ORIGINAL WELLS BPMV 15-04 WIWPW*00267-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NENW) ORIGINAL WELLS - BPMV 15-07 WIW PW*00268-00-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 15-08 WIWPW*00268-20-00-1 WY SUBLETTE .4722000 .4623532 .4722000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 36-29N-113WNWSW ORIGINAL WELLS BPMV 15-1 PW*00265-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-13 PW(TAW*00265-50-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSW) ORIGINAL WELLS BPMV 15-15 PW*00265-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-16 PW(TA)*00265-70-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-17 PW*00265-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS -BPMV 15-18 PW(TA)*00265-90-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-19 PW(TA)*00266-00-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 36-29N-113WSESW ORIGINAL WELLS BPMV 15-22 WIWPW*00266-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113 W (SWSW) ORIGINAL WELLS BPMV 15-23 PW*00266-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS BPMV 15-24 PW*00266-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 15-25WIW PW*00266-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-27 WIWPW*00266-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS - BPMV 15-28 WIW PW*00266-90-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSE) ORIGINAL WELLS BPMV 15-30 (WIW)PW*00267-10-00-1WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SENW) ORIGINAL WELLS BPMV 15-31 PW*00267-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NENW) ORIGINAL WELLS BPMV 15-32 PW*00267-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-34WIW PW*00267-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SENW) ORIGINAL WELLS BPMV 15-35 PW*00267-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-36 PW*00267-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS - BPMV 2-35 PW*00268-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 35-29N-113W (NESE) ORIGINAL WELLS BPMV 2-38 PW*00268-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 35-29N-113W (SESE) ORIGINAL WELLS BPMV 6-37 WIW PW&*00268-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SESE) ORIGINAL WELLS BPMV 6-41 PW&*00268-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SESE) ORIGINAL WELLS BPMV 6-54 PW&*00268-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SENE) ORIGINAL WELLS BPMV 6-55 PW&*00269-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SENE) ORIGINAL WELLS BPMV 6-61 PW&*00269-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (NESE) ORIGINAL WELLS - BPMV 6-70 PW&*00101-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 20-29N-113W (SENE) ORIGINAL WELLS BPMV 8-26 PW&*00270-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (NENW) ORIGINAL WELLS BPMV 8-35 WIW PW&*00270-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (SENW) ORIGINAL WELLS BUDD 1-10 LW&*00287-40-00-1 WY SUBLETTE 1.0000000 .7412500 1.0000000 .7412500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 10-29N-113W ORIGINAL WELLS BURLEY #1 LW02002-90-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1950' FEL & 920' FNL 19-28N-113W NWNE ORIGINAL WELLS C 1-23LW *00292-90-00-1 WY SUBLETTE 1.0000000 .8557812 1.0000000 .8557812 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 23-18N-113W ORIGINAL WELLS C 18-14 LW *00293-50-00-1 WY SUBLETTE 1.0000000 .8557812 1.0000000 .8557812 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-28N-113W ORIGINAL WELLS - C 19-23 LW&*00293-60-00-1 WY SUBLETTE 1.0000000 .7500000 1.0000000 .7500000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 23-28N-113W ORIGINAL WELLS C 23-03LW (TA)&*00293-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 3-28N-113W ORIGINAL WELLS C 31-25 LW *00294-10-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 25-28N-113W ORIGINAL WELLS C 39-03LW (TA)&*00294-20-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 43B-03LW&*00294-50-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 47-22 PW*00294-60-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENE 22-28N-113W ORIGINAL WELLS C 52-22 PW*00295-20-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NESE 22-28N-113W ORIGINAL WELLS - C 57-25 LW *00295-50-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 25-28N-113W ORIGINAL WELLS C 63-34 LW *00296-20-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 34-28N-113W ORIGINAL WELLS C 64-33 LW *00296-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 33-28N-113W ORIGINAL WELLS C 68-34 LW *00296-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-28N-113W ORIGINAL WELLS C 73-23 LW&*00297-00-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSW 23-28N-113W ORIGINAL WELLS C 74-22 PW&*00297-20-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS C 75-36 LW *00297-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWNE 36-28N-113W ORIGINAL WELLS - C 76-25 LW *00297-40-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 25-28N-113W ORIGINAL WELLS C 78-26 PW&*00297-60-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NWNW 26-28N-113W ORIGINAL WELLS C 84-03 LW&*00298-30-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 85-03 LW&*00298-40-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 3-28N-113W ORIGINAL WELLS CBU 1-04 PW 00315-30-00-1 WY SUBLETTE 1.0000000 .8263918 1.0000000 .8263918 OPERATOR: EOG FORMATION: FRONTIER A DESCRIPTION: SESE 4-28N-113W ORIGINAL WELLS CBU 11-34 PW 00315-50-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 13-25 PW 00315-70-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NWNE 25-28N-113W ORIGINAL WELLS - CBU 14-36 PW 00315-80-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NESW 36-28N-113W ORIGINAL WELLS CBU 16-25 LW00315-90-00-2 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWSW 25-28N-113W ORIGINAL WELLS CBU 17-35 PW 00316-00-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SWSE 35-28N-113W ORIGINAL WELLS CBU 18-34 PW 00316-10-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SESW 34-28N-113W ORIGINAL WELLS CBU 19-34 PW 00316-20-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NENE 34-28N-113W ORIGINAL WELLS CBU 2-35 PW 00316-30-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SENW 35-28N-113W ORIGINAL WELLS CBU 20-34 PW 00316-40-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NENW 34-28N-113W ORIGINAL WELLS - CBU 22-35 PW 00316-60-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SESW 35-28N-113W ORIGINAL WELLS CBU 22-35 (TGS)PW00316-60-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SESW 35-28N-113W ORIGINAL WELLS CBU 23-34 PW 00316-70-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SENE 34-28N-113W ORIGINAL WELLS CBU 23-34 (TGS)PW 00316-70-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SENE 34-28N-113W ORIGINAL WELLS CBU 26-34 PW 00316-90-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E"(F2 ZONE) DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 26-34 (TGS)PW 00316-90-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" (F1 TGS) DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 27-34 PW 00317-00-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNE 34-28N-113W ORIGINAL WELLS - CBU 27-34 (TGS)PW00317-00-00-2WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWNE 34-28N-113W ORIGINAL WELLS CBU 28-23 PW 01970-40-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER "B" DESCRIPTION: 860' FNL & 1780' FWL, SEC 23-28N-113W(NENW) ORIGINAL WELLS CBU 3-34 PW 00317-10-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NWSE 34-28N-113W ORIGINAL WELLS CBU 36-26 PW 00317-20-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SWSE 26-28N-113W ORIGINAL WELLS CBU 36-26(LW) 00317-20-00-2 WY SUBLETTE 1.0000000 .8321055 1.0000000 .8321055 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSE 26-28N-113W ORIGINAL WELLS CBU 38-14 LW01970-50-00-2 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557813 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSW 14-28N-113W ORIGINAL WELLS CBU 38-14 PW 01970-50-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER PA "B" DESCRIPTION: 460' FSL, 460' FWL, SEC 14-28N-113W(SWSW) ORIGINAL WELLS - CBU 5-14 PW 00317-40-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER "B" DESCRIPTION: NESW 14-28N-113W ORIGINAL WELLS - CBU 6-30LW *00317-50-00-2 WY SUBLETTE 1.0000000 .8355264 1.0000000 .8355264 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 30-28N-112W ORIGINAL WELLS CBU 6-30 PW*00317-50-00-1 WY SUBLETTE 1.0000000 .8355265 1.0000000 .8355265 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 30-28N-112W (NWSE) ORIGINAL WELLS CBU 7-27 PW 00317-70-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENW 27-29N-113W ORIGINAL WELLS CBU 9-26LW00317-80-00-1 WY SUBLETTE 1.0000000 .8090191 1.0000000 .8090191 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 26-28N-113W ORIGINAL WELLS CDR CRK 1-3200318-10-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNE 32-27N-113W ORIGINAL WELLS CDR CRK 12-32 CW 00149-10-00-1 WY SUBLETTE 1.0000000 .8475000 1.0000000 .8475000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 574' FSL & 1223' FEL 32-27N-113W (SESE) ORIGINAL WELLS WELL NAME WELL NUMBER ST COUNTY BPO BPO APO APO - CDR CRK 2-3300101-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SESE 33-27N-113W ORIGINAL WELLS CDR CRK 7-33 (BX)LW00148-90-00-1WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 7-33 (FR) LW00148-90-00-3WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 7-33 (M)LW00148-90-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 8-32LW00149-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2250' FNL & 2160' FEL 32-27N-113W (SWNE) ORIGINAL WELLS CH FED 2-17 00321-30-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SENW 17-30N-113W ORIGINAL WELLS CH FED 2-17 (TA)00321-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 17-30N-113W ORIGINAL WELLS -CH FED 24-0800321-40-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SESW 8-30N-113W ORIGINAL WELLS CH FED 24-08(TA)00321-40-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESW 8-30N-113W ORIGINAL WELLS CHAPEL 10-25LW*00322-70-00-1 WY SUBLETTE .0000000 .0166900 .0281676 .0235551 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 1312 FNL 1306 FWL CNW-25-28N-112W (LONG ISLAND PROSPECT) ORIGINAL WELLS CHRISMAN 1-10 LW*00327-00-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENE 10-29N-113W ORIGINAL WELLS CONNELLY A 1C-32LW00091-10-00-1WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 32-27N-113W ORIGINAL WELLS CONNELLY A 1C-33 BX 00346-60-00-2WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWSW 33-27N-113W ORIGINAL WELLS - CONNELLY B 1C-33LW00346-70-00-1WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CONNELLY B 1C-33LW00346-70-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 636' FNL, 662' FWL 33-27N-113W (NWNW) ORIGINAL WELLS CONNELLY B 1C-33LW00346-70-00-4 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CONNELLY B 1C-33 M00346-70-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CUTTHROAT 1-34LW01902-20-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY L ZONE DESCRIPTION: 1320' FEL, 2340' FNL 34-29N-113W S/2NE ORIGINAL WELLS DHU 4-10 PW*00063-50-00-1 WY SUBLETTE 1.0000000 .8327143 1.0000000 .8327143 OPERATOR: EOG FORMATION: ALMY "B" DESCRIPTION: SESW 10-30N-113W ORIGINAL WELLS DPU 1 PW*00747-30-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SWSW 14-27N-114W ORIGINAL WELLS DPU 10 PW*00747-60-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SENE 10-27N-114W ORIGINAL WELLS -DPU 11 PW*00747-70-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NWSE 34-28N-114W ORIGINAL WELLS DPU 13 PW*00747-80-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SWNE 14-27N-114W ORIGINAL WELLS DPU 14 PW*00747-90-00-1 WY SUBLETTE .4074307 .3519728 .4074307 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NESE 4-27N-114W ORIGINAL WELLS DPU 22 FR PW*00749-10-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: NWNW 24-27N-114W ORIGINAL WELLS DPU 23 PW*00749-20-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: NWSE 4-27N-114W ORIGINAL WELLS DPU 23 PW*00749-30-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: NWSE 4-27N-114W ORIGINAL WELLS DPU 26 PW*00749-80-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: NUGGET DESCRIPTION: NESW 10-27N-114W ORIGINAL WELLS -DPU 3 PW*00750-00-00-1 WY SUBLETTE .4074307 .3519728 .4074307 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: SWSW 4-27N-114W ORIGINAL WELLS DPU 6 FR PW*00750-70-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: SWNE 36-28N-114W ORIGINAL WELLS DPU 8 P/A*00750-80-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: SESE 35-28N-114W ORIGINAL WELLS DPU 9 PW*00751-00-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NESE 3-27N-114W ORIGINAL WELLS DRY BASIN 1-8 CW*00158-30-00-1 WY SUBLETTE 1.0000000 .8400000 1.0000000 .8400000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1222' FSL & 1027' FWL, SEC 8-28N-113W(SWSW) ORIGINAL WELLS DRY PINEY-BR A*99999-99-99-T WY SUBLETTE .2500000 .2165620 .2500000 .2165620 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: BEAR RIVER PA "A" ORIGINAL WELLS DRY PINEY-BR B*99999-99-99-U WY SUBLETTE .2500000 .2165620 .2500000 .2165620 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: BEAR RIVER PA "B" ORIGINAL WELLS - DRY PINEY-DAKOTA A*99999-99-99-VWY SUBLETTE .2500000 .2165620 .2500000 .2165620 OPERATOR: WEXPRO COMPANYFORMATION: DAKOTA DESCRIPTION: DAKOTA PA "A" ORIGINAL WELLS DRY PINEY-FRONT. B-C*99999-99-99-SWY SUBLETTE .3089990 .2671000 .3089990 .2671000 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: CONSL. FRONTIER PA "B-C" ORIGINAL WELLS DRY PINEY-FRONTIER A*99999-99-99-RWY SUBLETTE .2412290 .2071550 .2412290 .2071550 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: FRONTIER PA "A" ORIGINAL WELLS DRY PINEY-NUGGET *99999-99-99-EWY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: NUGGET DESCRIPTION: NUGGET PA "A" ORIGINAL WELLS - E 22-31 LW *00069-10-00-1 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557813 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 31-28N-112W ORIGINAL WELLS ELB R 1-29 PW*00768-30-00-1 WY SUBLETTE .8125000 .7034374 .8125000 .7034374 OPERATOR: EOG FORMATION: ALMY R-1 DESCRIPTION: 29-27N-112W, NESE ORIGINAL WELLS ELB R 7-32LW *00768-50-00-1 WY SUBLETTE .8125000 .6562510 .8125000 .6562510 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 32-27N-112W, NWNE ORIGINAL WELLS - ELB R 8-29 PW*00768-60-00-1 WY SUBLETTE .7500000 .6562510 .7500000 .6562510 OPERATOR: EOG FORMATION: ALMY R-8 DESCRIPTION: 29-27N-112W, LOT 7(NWSE) ORIGINAL WELLS ELB R 9-29LW *00768-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 29-27N-112W, SWNE ORIGINAL WELLS ELB 1-33 PW 00768-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 33-27N-112W ORIGINAL WELLS ELB 12-27 LW00769-20-00-1 WY SUBLETTE .5000000 .4180850 .5000000 .4180850 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 27-27N-112W ORIGINAL WELLS ELB 15-29 PW 00769-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 29-27N-112W ORIGINAL WELLS ELB 17-33 PW 00769-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 33-27N-112W ORIGINAL WELLS ELB 19-28 PW 00769-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 28-27N-112W ORIGINAL WELLS - ELB 2A-33 PW 00770-10-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENW 33-27N-112W ORIGINAL WELLS ELB 20-21 PW 00770-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 21-27N-112W ORIGINAL WELLS ELB 21-29 PW 00770-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 29-27N-112W ORIGINAL WELLS ELB 22-32 PW 00770-60-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 32-27N-112W ORIGINAL WELLS ELB 25-32 PW 00770-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 32-27N-112W ORIGINAL WELLS ELB 27-32 PW 00771-10-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 27-27N-112W ORIGINAL WELLS ELB 29-28 PW 00771-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESE 28-27N-112W ORIGINAL WELLS - ELB 30-21 PW 00771-40-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 8 21-27N-112W ORIGINAL WELLS ELB 31-21 PW 02147-40-00-1 WY SUBLETTE .5137380 .4433424 .5137380 .4433424 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 630' FNL, 825' FEL 21-27N-112W NENE ORIGINAL WELLS ELB 32-33 PW 00771-60-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 33-27N-112W ORIGINAL WELLS ELB 33-28 PW 00771-70-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 28-27N-112W ORIGINAL WELLS ELB 40-32 PW*00772-50-00-1 WY SUBLETTE .4533659 .3940400 .4533659 .3940400 OPERATOR: EOG FORMATION: MESA "A" DESCRIPTION: 32-27N-112W, SWNE ORIGINAL WELLS ELB 41-28 PW 00151-70-00-1 WY SUBLETTE 1.0000000 .8656687 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 28-27N-112W ORIGINAL WELLS ELB 5-28 PW 00773-00-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 28-27N-112W ORIGINAL WELLS - ELB 68-22 PW 00164-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWSW 22-27N-112W ORIGINAL WELLS ELB 7-29 PW 00773-20-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 29-27N-112W ORIGINAL WELLS ELB 8-32 PW 00773-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 32-27N-112W ORIGINAL WELLS FEDERAL 10-29LW*00111-90-00-1WY SUBLETTE.3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: 1320 FNL 1320 FWL (NW-29-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL30-15 CW*00110-40-00-1 WY SUBLETTE .3181080 .2477266 .2544864 .2045886 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER DESCRIPTION: SW-15-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-05 LW*00109-80-00-1 WY SUBLETTE .3181080 .2521005 .2193040 .1693282 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW 5-27N-111W ORIGINAL WELLS FEDERAL 10-17 LW*00110-50-00-1 WY SUBLETTE .3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-17-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS - FEDERAL 10-19 LW*00111-10-00-1WY SUBLETTE .2125000 .1710620 .2125000 .1710620 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-19-27N-111W ORIGINAL WELLS FEDERAL 10-20 LW *00111-20-00-1WY SUBLETTE .1130950 .0910415 .1130950 .0910415 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-20-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-28 LW *00111-70-00-1WY SUBLETTE .2907640 .2151653 .2907640 .2151653 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-28-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-30 CW*00112-20-00-1 WY SUBLETTE .2125000 .1722387 .2125000 .1722387 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-30-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-31 LW*00791-50-00-1 WY SUBLETTE .2491698 .1963644 .1789269 .1440362 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 938 FWL 1320 FNL (W2NW-31-28N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-32 LW*00112-40-00-1 WY SUBLETTE .2293561 .1697236 .2293561 .1697236 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SENW-32-27N-11W ORIGINAL WELLS FEDERAL 10-8(LW)*00110-20-00-1 WY SUBLETTE .2226760 .1781410 .2226760 .1781410 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-8-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS - FEDERAL 20-07 LW*00110-00-00-1WY SUBLETTE .2544864 .2083607 .2544864 .2083607 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NE 7-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-17 LW *00110-60-00-1WY SUBLETTE .1908648 .1517375 .1908648 .1517375 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: NWNE 17-27N-111W (NE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-20 LW *00111-30-00-1WY SUBLETTE .0954478 .0768349 .0954478 .0768349 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: E2-20-27N-111W (NE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-29 CW*00112-00-00-1 WY SUBLETTE .3101554 .2512656 .3101554 .2512656 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: 1120 FNL 1520 FEL (SE-29-27N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-08 CW*00110-30-00-1 WY SUBLETTE .2226760 .1765502 .2226760 .1765502 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-8-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-17 LW*00110-70-00-1 WY SUBLETTE .3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-17-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS - FEDERAL 30-20 CW*00111-40-00-1 WY SUBLETTE .0343370 .0300043 .0343370 .0300043 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 1120 FSL 1120 FWL (SWSW-20-27N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS - FEDERAL 30-28CW*00119-70-00-1WY SUBLETTE .2907640 .2151655 .2907640 .2151655 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: SW-28-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-31 LW *00109-70-00-1WY SUBLETTE .0704190 .0566873 .0704190 .0566873 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-31-28N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-06*00109-90-00-1WY SUBLETTE .2226760 .1781408 .2226760 .1781408 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE 6-27N-111W ORIGINAL WELLS FEDERAL 40-07 LW*00110-10-00-1 WY SUBLETTE .0000000 .0000000 .2544864 .1937274 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE 7-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-17 LW*01932-00-00-1 WY SUBLETTE .0473856 .0381454 .0473856 .0381454 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-17-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-20 LW*00111-50-00-1 WY SUBLETTE .0771502 .0607558 .0771502 .0607558 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: E2-20-27N-111W (SE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-29 CW*00112-10-00-1 WY SUBLETTE .3101554 .2512656 .3101554 .2512656 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: 1320 FEL 1320 FSL (SE-29-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS - FEDERAL 40-30 LW*00112-30-00-1WY SUBLETTE .2125000 .1710625 .2125000 .1710625 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-30-27N-111W ORIGINAL WELLS FEDERAL 40-32 LW *00112-50-00-1WY SUBLETTE .3181080 .2560768 .3181080 .2560768 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-32-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FFC 1-01LW&*00798-30-00-1 WY SUBLETTE .8750000 .7000000 .6125000 .5236875 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESE 1-27N-112W ORIGINAL WELLS FFC 1-15 PW 00797-70-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: 1650' FSL, 1650' FWL 15-27N-112W NESW ORIGINAL WELLS FFC 10-15 PW 00797-80-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: 2070' FEL, 2125' FNL 15-27N-112W SWNE ORIGINAL WELLS FFC 11-14 LW *00797-90-00-1 WY SUBLETTE 1.0000000 .7474281 1.0000000 .7474281 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: C NW 14-27N-112W ORIGINAL WELLS FFC 13-10 PW 01970-30-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 813' FSL, 2170' FEL 10-27N-112W SWSE ORIGINAL WELLS - FFC 2-12 CW 00798-00-00-1 WY SUBLETTE .8062500 .6843437 .8062500 .6843437 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 12-27N-112W ORIGINAL WELLS FFC 2-12 CW 00798-50-00-1 WY SUBLETTE .9000000 .7645000 .9000000 .7645000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SENE 12-27N-112W ORIGINAL WELLS FFC 3-12LW00798-60-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 3-12LW00798-60-00-2 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 3-12 (TGS)LW00798-60-00-3 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER (TGS) DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 4-13 LW 00798-70-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NENE 13-27N-112W ORIGINAL WELLS FFC 5-13LW00798-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NESE 13-27N-112W ORIGINAL WELLS FFC 6-31LW00798-90-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: SWNE 31-28N-111W ORIGINAL WELLS -FFC 7-31 (BR) CW00799-00-00-1WY SUBLETTE .0000000 .0000000 .6644060 .5448468 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: 1320' FSL, 519' FEL 31-28N-111W NWSE ORIGINAL WELLS FFC 8-30LW00799-10-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: NESW 30-28N-111W ORIGINAL WELLS FFCU 2-10 PW &*00798-00-00-2WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: SESW 10-27N-112W ORIGINAL WELLS FFF 1-1LW 00798-30-00-2 WY SUBLETTE .8750000 .7000000 .6125000 .5236875 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 1-27N-112W ORIGINAL WELLS FFF 7-31 (FRONT)CW00799-00-00-2 WY SUBLETTE .0000000 .0000000 .6644060 .5448468 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1320' FSL, 519' FEL 31-28N-111W NESE ORIGINAL WELLS FOG CRK 1-08 PW*00910-40-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SESW 8-28N-114W ORIGINAL WELLS FOG CRK 1-32 PW*00910-30-00-1 WY SUBLETTE .1145950 .0977064 .1145950 .0977064 OPERATOR: EXXON CO USAFORMATION: FRONTIER A DESCRIPTION: LOT 19 32-28N-114W ORIGINAL WELLS - FOG CRK 10-08 LW*00910-50-00-1WY SUBLETTE .1250000 .0990168 .1250000 .0990168 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: NENW 8-28N-113W (FOGARY CREEK PROSPECT) ORIGINAL WELLS FOG CRK 2-16 PW*00910-80-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SWNW 16-28N-114W ORIGINAL WELLS FOG CRK 3-04 LW*00910-90-00-1 WY SUBLETTE .2500000 .1950000 .1250000 .0990168 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: LOT 18 4-28N-114W ORIGINAL WELLS FOG CRK 4-17 PW*00911-00-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SWSE 17-28N-114W ORIGINAL WELLS FOG CRK 6-16 PW*00911-10-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: SWSE 16-28N-114W ORIGINAL WELLS FOG CRK 7-09LW*00911-20-00-1 WY SUBLETTE .6875000 .5128719 .3437500 .2774553 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: SWSE 9-28N-114W (W2SE4) ORIGINAL WELLS FOG CRK 8-20 PW*00911-30-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: NESE 20-28N-114W ORIGINAL WELLS - FOG CRK 9-21 PW*00911-40-00-1WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: NESW 21-28N-114W ORIGINAL WELLS GHU 3-32 PW*00939-80-00-1 WY SUBLETTE .5000000 .4275042 .5000000 .4275042 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNW 32-31N-113W ORIGINAL WELLS GHU 5-32 PW*00939-90-00-1 WY SUBLETTE .5000000 .4275042 .5000000 .4275042 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 32-31N-113W ORIGINAL WELLS GRB B 18-19 (BAX)PW02173-00-00-1WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: LOT 4, (SWSW), 19-27N-112W, 750' FSL & 560' FWL ORIGINAL WELLS GRB B 2-36 BAXTER PW00158-20-00-1WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 580' FNL & 2650' FEL (NWNE), 36-27N-113W ORIGINAL WELLS GRB B 4-36 (BAX)PW01975-30-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1900' FWL & 1700' FSL (NESW), 36,27N,113W ORIGINAL WELLS GRB B 5-36 BAX)PW01975-40-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1370' FSL & 1279' FEL, NESE, 36: 27N-113W ORIGINAL WELLS GRB B 6-1 (BAX)PW01975-50-00-1WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 518' FNL & 1467' FEL, LOT 37, 1-26N-113W ORIGINAL WELLS GRB T 14-34 PW*00946-10-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4493539 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 34-27N-113W, NENE ORIGINAL WELLS GRB T 15-27 PW*00946-20-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NWNE ORIGINAL WELLS GRB T 16A-27 PW*00946-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SWNE ORIGINAL WELLS GRB T 17-27 PW*00946-40-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NENE ORIGINAL WELLS GRB T 18-27 PW*00946-50-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SENE ORIGINAL WELLS GRB T 24-27 PW*00947-10-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NESE ORIGINAL WELLS - GRB T 26-35 PW*00947-20-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SWNW ORIGINAL WELLS GRB T 27-35 PW*00947-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV "A-B-C" DESCRIPTION: 35-27N-113W (NWNW) ORIGINAL WELLS GRB T 28-35 PW*00947-60-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NWSW ORIGINAL WELLS - GRB T 29-35 PW*00947-70-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NENW ORIGINAL WELLS GRB T 32-27 PW*00947-90-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SESE ORIGINAL WELLS GRB T 36-35 PW*00948-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SENW ORIGINAL WELLS GRB T 37-35 PW*00948-40-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NESW ORIGINAL WELLS - GRB T 39-35*00948-50-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SWSW ORIGINAL WELLS GRB T 44-31 PW*00948-90-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY T-41 DESCRIPTION: NESW 31-27N-112W ORIGINAL WELLS GRB T 60-34 PW*00949-90-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, SENE ORIGINAL WELLS GRB T 61-34 PW*00950-00-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, NESE ORIGINAL WELLS GRB T 62-34 PW*00950-10-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, SESE ORIGINAL WELLS GRB T 8-36 PW*00951-10-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY T-5 DESCRIPTION: 36-27N-113W, NESW ORIGINAL WELLS GRB 1-19 PW00951-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 19-27N-112W ORIGINAL WELLS - GRB 10-09 PW 00951-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 9-27N-112W ORIGINAL WELLS GRB 100-35 PW 00952-00-00-1 WY SUBLETTE .9190310 .7785252 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B (ZONE 2) DESCRIPTION: SEC. 35-27N-113W, (NWNW) ORIGINAL WELLS GRB 100-35 (TGS)PW00952-00-00-2 WY SUBLETTE .9190310 .7785252 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B (ZONE 1/TGS) DESCRIPTION: SEC. 35-27N-113W, (NWNW) ORIGINAL WELLS GRB 102-36 BR PW00159-50-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 560' FNL & 2700' FEL {NWNE}, SEC 36-27N-113W ORIGINAL WELLS GRB 102-36 F PW 00159-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 560' FNL & 2700' FEL {NWNE} SEC 36-27N-113W ORIGINAL WELLS GRB 13-17 PW 00952-20-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 17-27N-112W ORIGINAL WELLS GRB 14-20 PW 00952-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 20-27N-112W ORIGINAL WELLS - GRB 15-07 PW 00952-40-00-1 WY SUBLETTE 1.0000000 .8453506 1.0000000 .8453506 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: NENW 7-27N-112W ORIGINAL WELLS GRB 152-11 PW 00158-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2391' FEL & 2615' FNL, SEC. 11-26N-113W, (SWNE) ORIGINAL WELLS GRB 16-33 LW00952-50-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 33-28N-112W ORIGINAL WELLS GRB 19-35 BR PW 00952-90-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSE 35-27N-113W ORIGINAL WELLS GRB 19-35 F PW 00952-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSE 35-27N-113W ORIGINAL WELLS GRB 21-34 F PW 00953-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 34-27N-113W ORIGINAL WELLS - GRB 21-34 M PW 00953-40-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 34-27N-113W ORIGINAL WELLS - GRB 22-27 BR PW00953-50-00-2WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNE 27-27N-113W ORIGINAL WELLS GRB 22-27 F PW 00953-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 27-27N-113W ORIGINAL WELLS GRB 28-18 PW 00954-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 18-27N-112W ORIGINAL WELLS GRB 29-30 PW 00954-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 30-27N-112W ORIGINAL WELLS GRB 29-30 (BAX) PW00954-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 500' FNL & 1320' FWL, NENW 30-27N-112W ORIGINAL WELLS GRB 3-31 PW 00954-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSE 31-27N-112W ORIGINAL WELLS GRB 33-06 PW 00954-50-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SWSE 6-27N-112W ORIGINAL WELLS - GRB 35-07 PW 00954-70-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SESE 7-27N-112W ORIGINAL WELLS GRB 36-18 PW 00954-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 18-27N-112W ORIGINAL WELLS GRB 37-20 PW 00954-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 20-27N-112W ORIGINAL WELLS GRB 38-36 PW 00955-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1345' FNL & 500' FELSENE 36-27N-113W ORIGINAL WELLS GRB 38-36 (BAX)PW00955-00-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1345' FNL500' FEL, SENE, 36-27N-113W ORIGINAL WELLS GRB 39A-31 PW 00955-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1600' FNL & 1600' FWL, SEC. 31-27N-112W, (SENW) ORIGINAL WELLS GRB 39A-31 (BAX)PW00955-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1600' FNL & 1600' FWL, SEC. 31-27N-112W, (SENW) ORIGINAL WELLS - GRB 41-36 BRPW00955-40-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNW 36-27N-113W ORIGINAL WELLS GRB 41-36 F PW 00955-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 36-27N-113W ORIGINAL WELLS GRB 46A-1 (BAX)PW 00955-90-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 5262' FNL & 963' FEL, LOT 37, 1-26N-113W ORIGINAL WELLS GRB 49-19 PW 00956-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 19-27N-113W ORIGINAL WELLS GRB 49-19 BAXTERPW00956-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SESE 19-27N-113W ORIGINAL WELLS - GRB 50-30 PW 00956-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 30-27N-112W ORIGINAL WELLS GRB 50-30 (BAX)PW 00956-30-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SENE 30-27N-112W ORIGINAL WELLS GRB 52-35 BRPW00956-50-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSW 35-27N-113W ORIGINAL WELLS GRB 52-35 F PW 00956-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 35-27N-113W ORIGINAL WELLS GRB 54-36 F PW 00956-70-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSW 36-27N-113W ORIGINAL WELLS GRB 54-36 M PW 00956-70-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWSW 36-27N-113W ORIGINAL WELLS GRB 57-06 PW 00056-90-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENE 6-27N-112W ORIGINAL WELLS GRB 59-7 PW 00957-10-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SWNE 7-27N-112W ORIGINAL WELLS GRB 6-30 PW 00957-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 30-27N-112W ORIGINAL WELLS GRB 6-30 (BAX)PW00957-30-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSE 30-27N-112W ORIGINAL WELLS GRB 60-17 PW 00957-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 17-27N-112W ORIGINAL WELLS GRB 63-35 BR PW 00957-70-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 35-27N-113W ORIGINAL WELLS GRB 63-35 F PW 00957-70-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 35-27N-113W ORIGINAL WELLS GRB 66-17 PW 00958-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 17-27N-112W ORIGINAL WELLS GRB 67-06 PW 00958-20-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: NESW 6-27N-112W ORIGINAL WELLS GRB 68-30 PW 00958-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 30-27N-113W ORIGINAL WELLS - GRB 68-30 (BAX)PW00958-30-00-2WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESW 30-27N-113W, 1500' FWL & 2150' FSL ORIGINAL WELLS GRB 69-19 PW 00958-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 19-27N-112W ORIGINAL WELLS GRB 69-19 (BAX)PW 00958-40-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1300' FNL & 1650' FWL NENW 19-27N-112W ORIGINAL WELLS GRB 7-06 PW 00958-50-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENW 6-27N-112W ORIGINAL WELLS GRB 70-19 PW 00958-60-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 19-27N-112W ORIGINAL WELLS GRB 70-19 (BAX)PW 00958-60-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESW 19-27N-112W ORIGINAL WELLS GRB 72-27 BR PW 00958-80-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 1407' FEL & 2532' FSL, SEC. 27-27N-113W, (NWSE) ORIGINAL WELLS - GRB 72-27 F PW00958-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1407' FEL & 2532' FSL, SEC. 27-27N-113W, (NWSE) ORIGINAL WELLS GRB 73-17 F PW 00958-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 17-27N-112W ORIGINAL WELLS GRB 74-31 (BAX)PW 00959-00-00-3 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1000' FWL & 1350' FSL, E2SW, 31-27N-112W ORIGINAL WELLS GRB 74-31 F PW 00959-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: E2SW 31-27N-112W ORIGINAL WELLS GRB 74-31 M PW 00959-00-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: E2SW 31-27N-112W ORIGINAL WELLS GRB 75-31 PW 00959-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: E NE 31-27N-112W ORIGINAL WELLS GRB 75-31 (BAX)PW 00959-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547653 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENE 31-27N-112W ORIGINAL WELLS - GRB 8-36 BR PW00959-60-00-2 WY SUBLETTE.8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NESE, 36-27N-113W ORIGINAL WELLS GRB 8-36 F PW 00959-60-00-1 WY SUBLETTE.9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 36-27N-113W ORIGINAL WELLS GRB 81-36 BR PW 00959-80-00-2 WY SUBLETTE1.0000000 .8509818 .8289570 .7060031 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNE 36-27N-113W ORIGINAL WELLS GRB 81-36 F PW 00959-80-00-1 WY SUBLETTE1.0000000 .8358373 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 36-27N-113W ORIGINAL WELLS GRB 82-6 (BAX)PW 00959-90-00-2 WY SUBLETTE1.0000000 .8547652 1.0000000 .8547652 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 800' FWL & 2200' FNL, SENW, 6-26N-112W ORIGINAL WELLS GRB 88-35 PW 00960-60-00-1 WY SUBLETTE.9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 35-27N-113W ORIGINAL WELLS GRB 90-34 PW 00152-00-00-1 WY SUBLETTE.9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 480' FEL & 2358' FNL {SENE} SECTION 34, T27N, R113W ORIGINAL WELLS - GRB 94-27 F PW 00961-40-00-1 WY SUBLETTE .9190310 .7670147 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 27-27N-113W ORIGINAL WELLS GRB 98-27 (TGS)PW 00152-10-00-3 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 98-27 BR/MUDPW00152-10-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER/85% ALLOCATION DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 98-27 FR 2 PW00152-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 99-27 BR PW 00961-60-00-2 WY SUBLETTE .7906803 .6805900 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 27-27N-113W ORIGINAL WELLS GRB 99-27 F PW 00961-60-00-1 WY SUBLETTE .9190310 .7670147 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 27-27N-113W ORIGINAL WELLS GULF STATE 1-16LW*00964-90-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-112W, (SESW) ORIGINAL WELLS - HAIRSEAR 1-22 LW01902-40-00-1WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY K SAND DESCRIPTION: 690' FEL & 1730' FNL, SEC. 22-29N-113W, (SENE) ORIGINAL WELLS HORSESHOE BEND 1-20 00113-00-00-1WY SUBLETTE 1.0000000 .8750000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 20-27N-112W ORIGINAL WELLS HORSESHOE BEND 2-21 00113-10-00-1WY SUBLETTE 1.0000000 .8750000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 21-27N-112W ORIGINAL WELLS ISE 16-17 (P&A)PW*00662-90-00-1 WY SUBLETTE .4502007 .3790573 .4502007 .3790573 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 2530' FEL & 2180' FSL, 17-29N-112W(NWSE) ORIGINAL WELLS ISENHOUR-ALMY*99999-99-99-F WY SUBLETTE .4502000 .3790457 .4502000 .3790457 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY PA ORIGINAL WELLS JORY HILL 1-29 (M)CW01990-80-00-2WY SUBLETTE .5000000 .4068750 .5000000 .4068750 OPERATOR: EOG FORMATION: MUDDY 16% ALLOCATION DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W (SENE) ORIGINAL WELLS - JORY HILL 1-29 FR CW01990-80-00-1WY SUBLETTE.5000000 .4068750 .5000000 .4068750 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W, (SENE) ORIGINAL WELLS JORY HILL 1-29 FR CW01990-80-00-4WY SUBLETTE .5000000 .4068750 .5000000 .4068750 OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W, (SENE) ORIGINAL WELLS LIU 3-24 PW*01045-70-00-1 WY SUBLETTE 1.0000000 .7949999 1.0000000 .7949999 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWSW 24-29N-112W ORIGINAL WELLS LIU 4-23 PW*01046-30-00-1 WY SUBLETTE 1.0000000 .7499999 1.0000000 .7949999 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NESE 23-29N-112W ORIGINAL WELLS LONG ISLAND ALMY A-B*99999-99-99-DWY SUBLETTE 1.0000000 .8250688 1.0000000 .8250688 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY PA A-B ORIGINAL WELLS LONG ISLAND MESV*99999-99-99-C WY SUBLETTE 1.0000000 .7950000 1.0000000 .7950000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: MESAVERDE PA ORIGINAL WELLS M & M 1-14LW&*01601-60-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNW 14-29N-113W ORIGINAL WELLS - MASON 3-18LW *01615-50-00-1WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSW 18-31N-113W ORIGINAL WELLS MCD ALMY PA A*99999-99-99-G WY SUBLETTE 1.0000000 .8532585 1.0000000 .8532585 OPERATOR: EOG FORMATION: ALMY A DESCRIPTION: ALMY PA A ORIGINAL WELLS MCD ALMY PA B-F*99999-99-99-H WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY B-F DESCRIPTION: ALMY PA B-F ORIGINAL WELLS MCD ALMY PA C-D*99999-99-99-I WY SUBLETTE 1.0000000 .8446556 1.0000000 .8446556 OPERATOR: EOG FORMATION: ALMY C-D DESCRIPTION: ALMY PA C-D ORIGINAL WELLS MCD ALMY PA E*99999-99-99-J WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: ALMY E DESCRIPTION: ALMY PA E ORIGINAL WELLS MCD ALMY PA H*99999-99-99-K WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY H DESCRIPTION: ALMY PA H ORIGINAL WELLS MCD ALMY PA I*99999-99-99-L WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY I DESCRIPTION: ALMY PA I ORIGINAL WELLS - MCD ALMY PA J*99999-99-99-M WY SUBLETTE .5000000 .4225000 .5000000 .4225000 OPERATOR: EOG FORMATION: ALMY J DESCRIPTION: ALMY PA J ORIGINAL WELLS MCD 87-18 PW&*00435-00-00-1 WY SUBLETTE .5000000 .4225000 .5000000 .4225000 OPERATOR: EOG FORMATION: ALMY J DESCRIPTION: NENE 18-28N-112W ORIGINAL WELLS MICK CRK FED 1-17 LW*01078-80-00-1WY SUBLETTE .7000000 .5792500 .7000000 .5792500 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NWNW 17-32N-114W660' FNL & 460' FWL ORIGINAL WELLS MILLS 1-22LW00442-60-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS MILLS 1-22 (TGS)LW00442-60-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS MILLS 2-23LW&*00442-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 23-27N-113W, SWSW ORIGINAL WELLS MP 10-3 LW00150-00-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 718' FSL & 280' FEL, SEC. 3-29N-113W, (SESE) ORIGINAL WELLS - MP 12-1001079-40-00-1 WY SUBLETTE 1.0000000 .8101500 1.0000000 .8101500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENE 10-29N-113W ORIGINAL WELLS - MP 14-1101079-50-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWNW 11-29N-113W ORIGINAL WELLS MP 16-10 LW 01079-60-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 460' FEL, & 2060' FSL, SEC. 10-29N-113W, (NESE) ORIGINAL WELLS MP 17-11 LW 01079-70-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 661' FWL, & 2800' FSL, SEC. 11-29N-113W, (NWSW) ORIGINAL WELLS MP 19-10 LW 01079-80-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 792' FSL, & 460' FEL, SEC. 10-29N-113W, (SESE) ORIGINAL WELLS MP 20-11LW01079-90-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 800' FSL, & 861' FWL, SEC. 11-29N-113W, (SWSW) ORIGINAL WELLS MP 21-11LW00149-80-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 710' FSL & 1980' FWL, SEC. 11-29N-113W, (SESW) ORIGINAL WELLS - MP 23-1401080-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW 14-29N-113W ORIGINAL WELLS MP 3-03 01079-10-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NESE 03-29N-113W ORIGINAL WELLS - MP 4-11 01079-20-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWNW 11-29N-113W ORIGINAL WELLS MP 5-3LW00150-20-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2022' FNL & 461' FEL, SEC. 3-29N-113W, (SENE) ORIGINAL WELLS MP 7-3LW00150-10-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2029' FSL & 1830' FEL, SEC. 3-29N-113W, (NWSE) ORIGINAL WELLS MP 9-03 LW01080-10-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSE 03-29N-113W ORIGINAL WELLS NCB 1-2300315-20-00-1 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557812 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 23-28N-113W ORIGINAL WELLS - NCB 2-23 CW 01094-10-00-1 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1331'FEL & 2098' FSL, SEC. 23-28N-113W, (TR 45) ORIGINAL WELLS NCB 2-23 CW 01094-10-00-2 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1331'FEL & 2098' FSL, SEC. 23-28N-113W, (TR 45) ORIGINAL WELLS - NCB 4-23 CW 01989-10-00-1 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 600'FSL & 1100'FEL, SEC. 23-28N-113W, (L0T 7) ORIGINAL WELLS NCB 4-23 CW 01989-10-00-2 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 600'FSL & 1100'FEL, SEC. 23-28N-113W, (LOT 7) ORIGINAL WELLS NEW FORK MESA 1-15*00157-90-00-1WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1169' FSL & 1122' FEL, SEC. 15-28N-113W, (SESE) ORIGINAL WELLS NLB 19-09 PW 00463-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SENW ORIGINAL WELLS NLB 20-08 PW 00463-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, SWNE ORIGINAL WELLS NLB 21-04 PW 00463-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 4-27N-113W, NWSW ORIGINAL WELLS - NLB 22-17 PW 00464-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, NESE ORIGINAL WELLS - NLB 23-16 PW 00464-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SESW ORIGINAL WELLS NLB 24-33 PW 00464-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SWNW ORIGINAL WELLS NLB 25-05 PW 00464-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, NWSE ORIGINAL WELLS NLB 26-09 PW 00464-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWSW ORIGINAL WELLS NLB 27-17 PW 00464-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NENW ORIGINAL WELLS NLB 27-17 (TGS)PW 00464-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NENW ORIGINAL WELLS - NLB 30-16 PW 00464-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 16-27N-113W, NESE ORIGINAL WELLS NLB 30-16 (TGS)PW 00464-90-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 16-27N-113W, NESE ORIGINAL WELLS NLB 31-08 PW 00465-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NWSW ORIGINAL WELLS NLB 32-05 PW 00465-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWSW5-27N-113W ORIGINAL WELLS NLB 32-05 (TGS)PW 00465-10-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWSW5-27N-113W ORIGINAL WELLS NLB 33-17 PW 00465-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NESW ORIGINAL WELLS NLB 33-17 (TGS)PW 00465-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NESW ORIGINAL WELLS -NLB 34-21 PW 00465-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 21-27N-113W, NWNW ORIGINAL WELLS NLB 34-21 (TGS)PW 00465-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 21-27N-113W, NWNW ORIGINAL WELLS NLB 35-34 PW 00465-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 34-28N-13W, SWNW ORIGINAL WELLS NLB 35-34 (TGS)PW 00465-40-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 34-28N-13W, SWNW ORIGINAL WELLS NLB 36-33 PW 00465-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS NLB 36-33 (TGS)PW 00465-50-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS NLB 37-05 PW 00465-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 5-27N-113W, SWSE2153' FEL & 84' FSL ORIGINAL WELLS - NLB 37-05 (TGS)PW00465-60-00-1WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 5-27N-113W, SWSE2153' FEL & 84' FSL ORIGINAL WELLS NLB 38-08 PW 00465-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 8-27N-113W, NWNW ORIGINAL WELLS NLB 38-08 (TGS)PW 00465-70-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 8-27N-113W, NWNW ORIGINAL WELLS NLB 39-17 PW 00465-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NENE ORIGINAL WELLS NLB 39-17 (TGS)PW00465-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NENE ORIGINAL WELLS NLB 40-33 PW 00157-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, NENE ORIGINAL WELLS NLB 40-33 (TGS)PW 00157-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, NENE ORIGINAL WELLS -NLB 43-05 PW 00466-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SWNE 5-27N-113W ORIGINAL WELLS NLB 43-05 (TGS)PW 00466-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SWNE 5-27N-113W ORIGINAL WELLS NLB 44-34 PW 00466-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 34-28N-113W, SWSW ORIGINAL WELLS NLB 44-34 (TGS)PW 00466-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 34-28N-113W, SWSW ORIGINAL WELLS NLB 45-33 PW 00466-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 33-28N-113W, LOT 3 ORIGINAL WELLS NLB 45-33 (TGS)PW 00466-40-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 33-28N-113W, LOT 3 ORIGINAL WELLS NLB 46-33 PW 00466-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNE 33-28N-113W ORIGINAL WELLS - NLB 46-33 (TGS)PW00466-50-00-2WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWNE 33-28N-113W ORIGINAL WELLS NLB 48-04 PW 00466-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 4-27N-113W, NWSE ORIGINAL WELLS NLB 48-04 (TGS)PW 00466-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 4-27N-113W, NWSE ORIGINAL WELLS NLB 49-09 PW 00466-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 9-27N-113W, NWNE ORIGINAL WELLS NLB 49-09 (TGS)PW 00466-70-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 9-27N-113W, NWNE ORIGINAL WELLS NLB 51-16 PW 01980-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 16-27N-113W, NENE ORIGINAL WELLS NLB 51-16 (TGS)PW 01980-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 16-27N-113W, NENE ORIGINAL WELLS - NLB 52-16 PW 00154-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, NWSE ORIGINAL WELLS NLB 52-16 (TGS)PW 00154-10-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, NWSE ORIGINAL WELLS NLB 53-21 PW 00154-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENW ORIGINAL WELLS - NLB 53-21 (TGS)PW 00154-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENW ORIGINAL WELLS NLB 54-20 PW 00154-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, SWNE ORIGINAL WELLS NLB 54-20 (TGS)PW 00154-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, SWNE ORIGINAL WELLS NLB 55-17 PW 00466-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, SWSE ORIGINAL WELLS -171- - NLB 56-17 PW 00467-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, SENW ORIGINAL WELLS NLB 56-17 (TGS)PW 00467-00-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, SENW ORIGINAL WELLS NLB 59-09 PW 00107-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWNW ORIGINAL WELLS NLB 59-09 (TGS)PW 00107-90-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWNW ORIGINAL WELLS NPC 1-30LW *01092-10-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NENW 30-31N-113W ORIGINAL WELLS NPC 2-19LW *00101-70-00-2 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW SEC 19-31N-113W ORIGINAL WELLS NPC 2-19LW *00101-70-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 660' FNL & 1100' FWL {NWNW} SEC. 19-31N-113W ORIGINAL WELLS - PSU 12-30 PW*00490-80-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (NESW) ORIGINAL WELLS PSU 25-30 WIW PW P&A*00491-50-00-1WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (SENW) ORIGINAL WELLS PSU 29-02 PW(TA)*00491-80-00-1WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 2-28N-112W (LOT 5) NENE ORIGINAL WELLS PSU 3-31 PW*00491-90-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 31-29N-112W (NENW) ORIGINAL WELLS PSU 5-31 PW*00492-30-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 31-29N-112W (NENW) ORIGINAL WELLS PSU 6-30 PW*00492-40-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (SESW) ORIGINAL WELLS PSU 7-31 PW*00492-50-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: 1979' FNL & 668' FWL, SEC 31-29N-112W (SENW) ORIGINAL WELLS - RED HILL 1-18 CW00894-60-00-1WY SUBLETTE .9487350 .8115174 .9487350 .8115174 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 18-27N-112W ORIGINAL WELLS RIPPES DRAW 1-15LW00503-00-00-1 WY SUBLETTE 1.0000000 .8270000 1.0000000 .8270000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 1341' FEL, 1734' FSL, 15-30N-113WNWSE ORIGINAL WELLS RUBEN ALMY STRAY 3&4*99999-99-99-OWY SUBLETTE .6195350 .5052063 .6195350 .5052063 OPERATOR: EOG FORMATION: ALMY STRAY 3 & 4 DESCRIPTION: ALMY STRAY 3 & 4 ORIGINAL WELLS S 11-28 LW&*00407-40-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 28-30N-113W ORIGINAL WELLS S 14-21 LW&*00407-70-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NESE 21-30N-113W ORIGINAL WELLS S 18-21 LW00407-80-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 21-30N-113W ORIGINAL WELLS - S 19-28 LW&*00407-90-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1980' FNL & 1930' FWL28-30N-113W (SENW) ORIGINAL WELLS - S 2-21LW&*00408-00-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 21-30N-113W ORIGINAL WELLS S 21-28 00408-20-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 28-30N-113W ORIGINAL WELLS S 22-33 LW00408-30-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 1048' FNL & 661' FEL 33-30N-113WNENE ORIGINAL WELLS S 24-28 LW00408-40-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 28-30N-113W ORIGINAL WELLS S 25-34LW 00408-50-00-1 WY SUBLETTE 1.0000000 .8325100 1.0000000 .8325100 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1950' FSL & 750' FWL, SEC. 34-30N-113W, (NWSW) ORIGINAL WELLS S 26-33 LW00408-60-00-1 WY SUBLETTE 1.0000000 .8217500 1.0000000 .8217500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW 33-30N-113W ORIGINAL WELLS S 27-33 LW00408-70-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2997' FSL, & 1369' FEL33-30N-113W(SWNE) ORIGINAL WELLS - S 28-28 LW *00408-80-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2880' FSL & 1601' FEL28-30N-113WSWSW ORIGINAL WELLS S 31-28 LW00408-90-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 28-30N-113W ORIGINAL WELLS S 32-33 LW00409-00-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 33-30N-113W ORIGINAL WELLS S 33-28 LW00409-10-00-1 WY SUBLETTE .5000000 .4095000 .5000000 .4095000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1926' FSL & 1159' FWL, 28-30N-113W NWSW ORIGINAL WELLS S 34-34 LW00409-20-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-30N-113W ORIGINAL WELLS S 35-03 LW00149-70-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 1010' FWL & 645' FNL, SEC. 3-29N-113W, (LOT 4) ORIGINAL WELLS S 4-34LW *00409-40-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 34-30N-113W ORIGINAL WELLS - S 40-33 LW00409-50-00-1 WY SUBLETTE1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWNE 33-30N-113W ORIGINAL WELLS - S 50-21 LW00101-60-00-1 WY SUBLETTE1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWSW 21-30N-113W ORIGINAL WELLS S 6-21LW&*00409-60-00-1 WY SUBLETTE1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 21-30N-113W ORIGINAL WELLS S 7-36LW *00409-70-00-1 WY SUBLETTE1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 36-30N-113W ORIGINAL WELLS SADDLE RIDGE-MESV*99999-99-99-A WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: MESAVERDE PA ORIGINAL WELLS SFE FED 4-24 CW &*00168-50-00-1 WY SUBLETTE 1.0000000 .8020060 1.0000000 .8020060 OPERATOR: EOG . FORMATION: TRANSITION DESCRIPTION: 1316' FWL & 1318' FNL, 24-28N-113W (NWNW) ORIGINAL WELLS SHB 1-08 (M)CW00519-20-00-1 WY SUBLETTE .9500000 .7748750 .9500000 .7748750 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 1308 FNL 1388 FEL NWNE-8-26N-113W (HOGBACK PROSPECT) ORIGINAL WELLS - SLB 2-28 VPU00528-40-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 2-28 (BAXTER)VPU00528-40-00-2WY SUBLETTE 1.0000000 .7628571 1.0000000 .7628571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 2-28 (TGS) VPU00528-40-00-3 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 3-33 (BAX)CW00528-70-00-2 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 542'FSL & 370'FWL33-27N-113WSWSW ORIGINAL WELLS SLB 3-33 (FRONT)CW00528-70-00-3 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 542'FSL & 370' FWL33-27N-113W SWSW ORIGINAL WELLS SLB 3-33 (MUD)CW 00528-70-00-1 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 542'FSL & 370' FWL33-27N-113W SWSW ORIGINAL WELLS SLB 4-3300528-80-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESE 33-27N-113W ORIGINAL WELLS -SLB 5-33 (BAXTER) LW00154-50-00-2WY SUBLETTE1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2050' FNL & 2450' FEL 33-27N-113W SWNE ORIGINAL WELLS SLB 5-33 (FR 1) LW00154-50-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: 2050' FNL & 2450' FEL, SEC. 33-27N-113W, (SWNE) ORIGINAL WELLS SLB 5-33 (MUDDY)LW00154-50-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY/FRONTIER 2 DESCRIPTION: 2050' FNL & 2450' FEL, SEC. 33-27N-113W, (SWNE) ORIGINAL WELLS SLB 6-28 VPU00528-90-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2/MUDDY DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 6-28 VPU00528-90-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 6-28 (TGS) VPU00528-90-00-3 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 7-28AVPU00529-00-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2/MUDDY DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS SLB 7-28AVPU00529-00-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS - SLB 7-28A (TGS)VPU00529-00-00-3WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS SLB 8-33 LW 00154-60-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 AND MUDDY DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 8-33 LW 00154-60-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 8-33 (TGS) LW 00154-60-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 9-33 LW 00154-90-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 AND MUDDY DESCRIPTION: 1053' FSL & 2417' FEL, SEC. 33-27N-113W, (SWSE) ORIGINAL WELLS -SLB 9-33 (BAXTER) LW00154-90-00-2WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1053' FSL & 2417' FEL 33-27N-113W SWSE ORIGINAL WELLS SLB 9-33 TGS LW 00154-90-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 1053' FSL & 2417' FEL, SEC. 33-27N-113W, (SWSE) ORIGINAL WELLS - STAR CORRAL UNIT*99999-99-99-BWY SUBLETTE 1.0000000 .8289655 1.0000000 .8289655 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY FORMATION PA "A" ORIGINAL WELLS SUPERIOR MARSHALL #1*00605-70-00-1WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-30N-113W ORIGINAL WELLS TAR ISL 1-33LW&*00608-20-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 33-28N-112W ORIGINAL WELLS TAR ISL 2-33 LW (TA)&*00608-30-00-1WY SUBLETTE1.0000000 .8125000 .5000000 .4225000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE-33-28N-112W ORIGINAL WELLS TERM. DRAW 3-15CW 01974-60-00-1 WY SUBLETTE 1.0000000 .8325837 1.0000000 .8325837 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 15-28N-113W, NWSW ORIGINAL WELLS THOMPSON 2-08 LW*00612-40-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 8-29N-113W ORIGINAL WELLS THOMPSON 3-08 LW*00612-50-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SESE 8-29N-113W ORIGINAL WELLS - TRESNER ST 5-36 LW*00156-20-00-1WY SUBLETTE1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNE 36-29N-113W ORIGINAL WELLS TRUE FED 10-22LW*01430-50-00-1 WY SUBLETTE .2653600 .2231580 .2653600 .2231580 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW 22-27N-111W ORIGINAL WELLS FEDERAL 30-04 LW*00112-60-00-1 WY SWEETWATER.0686748 .0515061 .0343370 .0276416 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NESW 4-26N-111W ORIGINAL WELLS NORTH RUGER 34-29 02188-50-00-1 WY SWEETWATER.8750000 .6837500 .7000000 .5700000 OPERATOR: EOG FORMATION: ALMOND DESCRIPTION: 1120' FSL & 1920' FEL29-15N-94W SWSE ORIGINAL WELLS SCHEDULE 1 CONVEYANCE OF PRODUCTION PAYMENT SCHEDULED QUANTITIES OF PRODUCTION PAYMENT HYDROCARBONS PROJECTED TO BE RECEIVED MMBTU'S MMBTU'S MONTH PER DAY PER MONTH Oct-93 16,003 496,093 Nov-93 16,537 496,110 Dec-93 16,003 496,093 Jan-94 50,256 1,557,936 Feb-94 50,256 1,407,168 Mar-94 50,256 1,557,936 Apr-94 50,256 1,507,680 May-94 50,256 1,557,936 Jun-94 50,256 1,507,680 Jul-94 50,256 1,557,936 Aug-94 50,256 1,557,936 Sep-94 50,256 1,507,680 Oct-94 50,256 1,557,936 Nov-94 50,256 1,507,680 Dec-94 50,256 1,557,936 Jan-95 50,256 1,557,936 Feb-95 50,256 1,407,168 Mar-95 50,256 1,557,936 Apr-95 50,256 1,507,680 May-95 50,256 1,557,936 Jun-95 50,256 1,507,680 Jul-95 50,256 1,557,936 Aug-95 50,256 1,557,936 Sep-95 50,256 1,507,680 Oct-95 50,256 1,557,936 Nov-95 50,255 1,507,650 Dec-95 50,255 1,557,905 Jan-96 50,256 1,557,936 Feb-96 50,256 1,457,424 Mar-96 50,256 1,557,936 Apr-96 50,256 1,507,680 May-96 50,256 1,557,936 Jun-96 50,256 1,507,680 Jul-96 50,256 1,557,936 Aug-96 50,256 1,557,936 Sep-96 50,256 1,507,680 Oct-96 50,256 1,557,936 Nov-96 50,256 1,507,680 Dec-96 50,256 1,557,936 Jan-97 50,256 1,557,936 Feb-97 50,256 1,407,168 Mar-97 50,256 1,557,936 Apr-97 50,256 1,507,680 May-97 50,256 1,557,936 Jun-97 50,256 1,507,680 Jul-97 50,256 1,557,936 Aug-97 50,256 1,557,936 SCHEDULE 1 CONVEYANCE OF PRODUCTION PAYMENT SCHEDULED QUANTITIES OF PRODUCTION PAYMENT HYDROCARBONS PROJECTED TO BE RECEIVED DETERMINATION MMBTU'S MMBTU'S PERIOD PER DAY PER MONTH Sep-97 50,256 1,507,680 Oct-97 50,256 1,557,936 Nov-97 50,256 1,507,680 Dec-97 50,256 1,557,936 Jan-98 50,256 1,557,936 Feb-98 50,256 1,407,168 Mar-98 50,256 1,557,936 Apr-98 50,256 1,507,680 May-98 50,256 1,557,936 Jun-98 50,256 1,507,680 Jul-98 50,256 1,557,936 Aug-98 50,256 1,557,936 Sep-98 50,256 1,507,680 Oct-98 50,256 1,557,936 Nov-98 50,256 1,507,680 Dec-98 50,256 1,557,936 Jan-99 50,256 1,557,936 Feb-99 50,256 1,407,168 Mar-99 50,256 1,557,936 3,214,669 97,778,731
EX-10.37 11 FOURTH AMENDMENT TO HYDROCARBON EXCHANGE AGREEMENT EXHIBIT 10.37 FOURTH AMENDMENT TO HYDROCARBON EXCHANGE AGREEMENT Reference for all purposes is hereby made to that certain Hydrocarbon Exchange Agreement (the "Original Exchange Agreement"), dated September 25, 1992, by and between ENRON OIL & GAS COMPANY, a Delaware corporation ("EOG") and CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Cactus"), pertaining to certain Hydrocarbons more particularly described therein, which Original Exchange Agreement was recorded as set forth on Attachment A hereto under the caption "Original Exchange Agreement." WHEREAS, the Original Exchange Agreement was amended by that certain unrecorded Amendment to Hydrocarbon Exchange Agreement (the "Amendment to Exchange Agreement") dated effective as of January 1, 1993 from EOG to Cactus; and WHEREAS, the Original Exchange Agreement was further amended by that certain First Amendment to Hydrocarbon Exchange Agreement (the "First Amendment to Exchange Agreement") dated effective as of April 1, 1993 from EOG to Cactus, recorded as set forth on Attachment A hereto under the caption "First Amendment to Exchange Agreement;" and WHEREAS, the Original Exchange Agreement was further amended by that certain Second Amendment to Hydrocarbon Exchange Agreement (the "Second Amendment to Exchange Agreement") dated effective as of July 1, 1993 from EOG to Cactus, recorded as set forth on Attachment A hereto under the caption "Second Amendment to Exchange Agreement;" and WHEREAS, subsequent to the execution, delivery and recordation of the Original Exchange Agreement, pursuant to the terms and provisions of the Amendment to Exchange Agreement, certain additional Cactus Points of Receipt were added to Exhibit C to the Original Exchange Agreement, and, pursuant to the First Amendment to Exchange Agreement and the Second Amendment to Exchange Agreement, certain properties described on Exhibit A to the Original Exchange Agreement have been deleted therefrom and other properties substituted therefor; and WHEREAS, the Original Exchange Agreement as amended by the Amendment to Exchange Agreement, the First Amendment to Exchange Agreement and the Second Amendment to Exchange Agreement is referred to herein as the "Exchange Agreement;" and WHEREAS, EOG and Cactus desire to amend the Exchange Agreement as hereinafter set forth effective as of October 1, 1993 (the "Effective Date") and to restate and amend Exhibits A and C to the Exchange Agreement to reflect the matters described above. NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars ($10.00) and other good and valuable consideration, cash in hand paid to EOG by Cactus, EOG and Cactus do hereby amend the Exchange Agreement as follows: 1. Capitalized terms used herein shall have the meanings given to them in the Exchange Agreement unless otherwise defined herein. 2. The term "Conveyance" as used in the Exchange Agreement shall mean that certain Conveyance of Production Payment dated September 25, 1992 from EOG to Cactus as amended by the First Amendment to Conveyance of Production Payment dated effective as of April 1, 1993 between EOG and Cactus, the Second Amendment to Conveyance of Production Payment dated effective as of July 1, 1993 from EOG to Cactus and the Third Amendment to Conveyance of Production Payment dated effective as of October 1, 1993 between EOG and Cactus, and as the same may be further amended, modified or supplemented from time to time. 3. Exhibits A and C to the Exchange Agreement are hereby amended by deleting same and substituting Exhibits A and C attached hereto in lieu thereof. Exhibits A and C attached hereto are made a part of the Exchange Agreement and supersede Exhibits A and C attached to the Exchange Agreement. 4. Except as expressly amended hereby, the Exchange Agreement shall remain in full force and effect as heretofore entered into and amended. EOG and Cactus ratify and confirm the Exchange Agreement as hereby amended. -2- EXECUTED in multiple originals this 29th day of October, 1993, but effective as of the Effective Date. EOG: ATTEST: ENRON OIL & GAS COMPANY By: By: Name: D. M. Ulak Name: Andrew N. Hoyle Title: Assistant Secretary Title: Vice President Cactus: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp., its General Partner ATTEST: By: By: Name: Elaine Overturf Name: Jere C. Overdyke, Jr. Title: Deputy Corporate Secretary Title: Vice President ATTACHMENTS AND EXHIBITS: Attachment A - Recordation Schedule - Original Exchange Agreement, First Amendment to Exchange Agreement and Second Amendment to Exchange Agreement -3- Exhibit A - Sources of Supply Exhibit C - Cactus Points of Receipt and Scheduled Amounts -4- STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by _____________________, as _____________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, on behalf of such corporation this _____ day of _____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: -5- STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by ______________________, as __________________ of Enron Big Piney Corp., a Delaware corporation, as General Partner on behalf of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, this _____ day of ____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: -6- Attachment A Attached to and made a part of that certain Fourth Amendment to Hydrocarbon Exchange Agreement DOCUMENT FILING ENTITY RECORDING REFERENCE Original Exchange County Clerk Book 318 PR, Page 1 Agreement Lincoln County File No. 755520 October 8, 1992 County Clerk Book 90 O&G, Page Sublette County 224 File No. 238876 October 2, 1992 Amendment to Exchange unrecorded unrecorded Agreement First Amendment to County Clerk Book 330 PR, Page 39 Exchange Lincoln County File No. 765868 Agreement June 4, 1993 County Clerk Book 92 O&G, Page Sublette County 333 File No. 241741 May 28, 1993 Second Amendment to County Clerk Book 336 PR, Page Exchange Lincoln County 696 Agreement File No. 772469 October 4, 1993 Exhibit A (Exchange Agreement) Sources of Supply
Page 1 LEASE LEASE NUMBER LESSOR DATE RECORDING ST COUNTY 50001-00 ENGER K CHRISMAN, ET AL 04/28/1950 BK 2 PG 623 WY SUBLETTE T029N R113W SEC-0010 E2SE4 T029N R113W SEC-0011 W/2SW 50003-00 ENGER K CHRISMAN, ET AL 07/01/1954 BK 10 PG 398 WY SUBLETTE T029N R112W SEC-0018 LOTS 1, 2, E2NW T029N R113W SEC-0011 E2SW, SE T029N R113W SEC-0012 S2SE, NWSW, S2SW T029N R113W SEC-0013 SESW, SENE, SE, NWNW, NWNE, NENE, NENW T029N R113W SEC-0014 N2NE, NENW T029N R113W SEC-0024 N2NE 50005-01 CHAS. P BUDD 11/24/1942 BK 1 PG 371 WY SUBLETTE T029N R113W SEC-0010 N2NE, SWNE 50005-02 THE FRANCES MARGARET GUIO 12/15/1987 BK 81 PG 327 WY SUBLETTE JUNE 16, 1982 FAMILY TRUST T029N R113W SEC-0010 NENE, SENW, SWNE, AS TO ALL DEPTHS BELOW 2,500 FT. 50008-01 PATRICK J QUEALY, ADMIN. 08/15/1957 BK 18 PG 136 WY SUBLETTE T027N R113W SEC-0028 50008-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 140 WY SUBLETTE T027N R113W SEC-0028 SWNE, S2NW 50011-00 USA EV 021983 08/01/1944 BK 31 PG 200 WY SUBLETTE T029N R113W SEC-0014 NWNW 50013-01 SELMER G LARSON 06/11/1957 BK 17 PG 2 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50013-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 144 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50018-00 WILLIAM J. MCGINNIS, ET UX 10/05/1946 BK 2 PG 109 WY SUBLETTE T026N R113W SEC-0023 N2SE (PART OF TR 45) T028N R113W SEC-0024 N2/SW (PART OF TR 45), S2NE, S2NW, (AKA TR 47) 50019-00 USA EV-021741 09/01/1946 BK 88 PG 783 WY SUBLETTE PAGE 2 T026N R113W SEC-0004 LOTS 1(39.30), 2(38.74), 3(38.18), 4(37.62), 5(40), 6(40), 7(40), 8(40), 9(40), 10(40), 11(40), 12(40), SE, NWSW T027N R113W SEC-0028 SESW, SWSE T027N R113W SEC-0029 SENE T027N R113W SEC-0032 W2SE, N2NE, SWNE T027N R113W SEC-0033 NWNE, S2NE, SE, NW 50020-00 USA EV-021743 03/01/1947 BK 86 PG 313 WY SUBLETTE T027N R113W SEC-0033 N2SW 50022-01 MATILDA BERTAGNOLLI, ET VIR 10/26/1956 BK 16 PG 150 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50022-02 THOMAS S HARROWER, ET UX 09/06/1957 BK 18 PG 2 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50027-00 USA W-04226 01/01/1951 BK 89 PG 154 WY SUBLETTE T030N R113W SEC-0028 SWNW, N2SW, E2NW, S2SW 50028-00 USA 2-0136178 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113N SEC-0021 S2 50047-00 USA EV-023313-A 02/01/1948 BK314 PG 227 WY LINCOLN T026N R112W SEC-0012 W2E2, LOTS 3,4 T026N R112W SEC-0013 NW, SW 50048-00 USA EV-023313-B 02/01/1948 BK288 PG 640 WY LINCOLN T026N R112W SEC-0012 W2 T026N R112W SEC-0013 LOT 3, W2NE, LOT 4, W2SE 50049-00 ST WY 0-2265 03/02/1944 BK314 PG 49 WY LINCOLN T026N R112W SEC-0016 NENE 50050-00 USA EV-025550 01/01/1948 BK 89 PG 98 WY SUBLETTE T027N R112W SEC-0027 W2 50051-00 USA EV-022929 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0034 NENE, NENE, SE, S2NE, W2 T027N R112W SEC-0035 PAGE 3 50052-00 USA EV-026056 12/01/1949 BK 9 PG 128 WY LINCOLN T026N R112W SEC-0011 NE, NENW, N2SW, SE, SESW, SWSW, S2NW T026N R112W SEC-0014 E2, E2NW, SW, W2NW 50053-00 USA EV-022930-A 09/01/1947 BK 8 PG 484 WY LINCOLN T026N R112W SEC-0010 SENE, SENW, SWNE, N2NE, N2NW, SWNW, SW4, N2SE, S2SE T026N R112W SEC-0015 NWNW, NENW, SENW, SWNW, SW, N2N3, S2NE, SE 50054-00 USA EV-022932 09/01/1947 BK 9 OG 66 WY SUBLETTE T026N R112W SEC-0002 NESE, NWSE, SENE, SW, SWNE, S2NW, S2SE, LOTS 1, 2, 3, 4 T026N R112W SEC-0003 S2, S2N2, LOTS 1, 2, 3, 4 T026N R112W SEC-0004 SE T026N R112W SEC-0009 N2, N2SE, SESE, SW, SWSE T026N R112W SEC-0011 NWNW 50088-00 USA W-92217 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0017 N2NW, SESW T028N R112W SEC-0018 NE, LOTS 1, 2, 3, E2NW, NESW T028N R112W SEC-0019 SWNE, E2SW, W2SE, E2NE, E2SE T028N R112W SEC-0020 W2SW. MW. E2SW 50094-00 USA EV-022261 09/01/1946 BK 90 PG 107 WY SUBLETTE T026N R113W SEC-0019 SE, SWNE, SENE, LOT 5, NWNE T028N R113W SEC-0031 E2NE T028N R113W SEC-0032 LOT 1, N2NW, SWNW 50101-00 USA EV-025991 04/01/1952 BK 89 PG 82 WY SUBLETTE T029N R113W SEC-0034 ALL 50113-00 MYRON EDGAR MILLS ET UX 05/20/1953 BK 5 PG 107 WY SUBLETTE T028N R113W SEC-0022 SESE T028N R113W SEC-0023 E/2SW, SWSW, SAID LANDS BEING NOW RESURVEYED INTO AND AS TRACT 44 50131-00 USA W-48904 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 LOT 1 (NENE - 39.78 AC), SENE T028N R113W SEC-0032 W2N2 PAGE 4 T028N R113W SEC-0032 LOT 6 (SESE- 47.69) E2NE, NESE T028N R113W SEC-0033 SWNW 50133-00 USA EV-010270-B 10/16/1939 BK 89 PS 112 WY SUBLETTE T027N R113W SEC-0021 N2N2 50134-00 USA W-0256493 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 3, 4, NE, N2SE T028N R113W SEC-0034 LOT 1, W2NW, NWSW 50135-00 USA W-0256 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0009 W2NE 50136-00 USA EV-026191 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 SESW. SWSE 50137-00 USA W-048780 07/01/1947 BK 89 PG 89 WY SUBLETTE T027N R113W SEC-0004 LOTS 2, 3, SWNE 50138-00 USA EV-022209 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 1, 2 N2SW 50139-00 USA W-9653 03/10/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 LOT 4, S2NW, N2SW, NWSE 50140-00 ST WY 0-847 09/16/1936 BK PG WY SUBLETTE T027N R113W SEC-0016 ALL 50141-00 USA EV-09561-A 06/20/1932 BK 89 PG 65 WY SUBLETTE T027N R113W SEC-0017 NE, E2NW, SE, NESW T027N R113W SEC-0020 NENE, NWNE, S2NE 50142-00 USA EV-021978 01/01/1940 BK 2 PG 173 WY SUBLETTE T027N R113W SEC-0004 SWSW T027N R113W SEC-0009 NW, E2SW, W2SE 50143-00 USA EV-07555 01/01/1940 BK 89 PG 70 WY SUBLETTE T027N R113W SEC-00094 W2SW 50144-00 USA EV-07671-A 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 SE PAGE 5 50145-00 USA EV-07671-B 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 N2, N2SW, S2SW 50147-00 USA W-48907 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 N2SE, SWNE, LOTS 2, 3, 4, S2NW, N2SW, S2S2 T028N R113W SEC-0033 SENW 50149-00 USA W-0125385 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0019 LOTS 3, 4 50150-00 USA W-0125387 01/01/1950 BK 85 PG 605 WY SUBLETTE T028N R112W SEC-0030 LOT 1 50151-00 USA W-0125388 06/01/1948 BK 85 PG 621 WY SUBLETTE T028N R113W SEC-0023 NENW, NWNE, LOTS 1, 2, 3, NENE T028N R113W SEC-0024 LOTS 3 (48 AC) LOT 4 (48.77 AC) 50152-00 USA EV-022756 09/01/1946 BK 89 PG 17 WY SUBLETTE T028N R113W SEC-0014 S2NW, SW, N2NW 50153-00 USA EV-023554 01/01/1948 BK 89 PG 19 WY SUBLETTE T028N R113W SEC-0026 SESW, S2SE, LOT 1, SENW, NESW, N2SE, NE 50154-00 USA EV-024756 06/01/1948 BK 67 PG 70 WY SUBLETTE T028N R113W SEC-0023 LOTS 5, 6, 7 T028N R113W SEC-0024 LOTS 5, 6, 7, 7, 8, TRACT 46 A&B T028N R113W SEC-0025 LOTS 1, 2, 3, 4, W2E2, E2W2, SWSW, W2N2, NWSW 50155-00 USA EV-024792 07/01/1948 BK 85 PG 614 WY SUBLETTE T028N R113W SEC-0034 LOT 2 50156-00 USA W-02985 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0035 LTS 1, 2, 3, 4, 5, 6, 7, W2NE, N2NW, SWNW, N2SW, NWSE 50157-00 USA W-02985-A 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0034 SENW 50158-00 USA W-046892 02/01/1957 BK 85 PG 582 WY SUBLETTE T028N R113W SEC-0034 E2N2, SWNE, N2SE, LOTS 3 & 4 50159-00 USA W-05283 02/01/1951 BK 31 PG 229 WY SUBLETTE T028N R113W SEC-0004 LOTS 5, 6, S2N2, N2SE, SESE, SWSE PAGE 6 50160-00 USA W-08056 09/01/1951 BK 32 PG 63 WY SUBLETTE T028N R113W SEC-0034 E2NW, NESE, NWNE 50161-00 USA W-10675 09/01/1950 BK 31 PG 274 WY SUBLETTE T029N R113W SEC-0035 W2SW, SESW, NESW 50162-00 USA W-10677 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 NESE, SENW, SESE, S2NE T029N R113W SEC-0027 NESE, SENW, SESE, S2NE 50163-00 USA W-10679 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R113W SEC-0003 S2/SW 50164-00 STATE OF WYOMING 0-11142 05/16/1951 BK 19 PG 243 WY SUBLETTE T028N R113W SEC-0005 E2SW, SE, NW (PART OF RESURVEY TRACT 54) 50165-00 ST WY 020810 06/16/1956 BK 85 PG 669 WY SUBLETTE T028N R113W SEC-0036 W2SW 50166-00 USA W-06861 07/01/1951 BK 85 PG 40 WY SUBLETTE T028N R113W SEC-0015 SENE, N2NE 50167-00 USA W-014074 06/01/1952 BK 89 PG 96 WY SUBLETTE T029N R113W SEC-0035 N2NW, SENW, SWNW 50169-00 USA W-0125384 05/01/1948 BK 31 PG 242 WY SUBLETTE T028N R113W SEC-0011 E2 T028N R113W SEC-0013 SW T028N R113W SEC-0014 SWNE, W2SE, N2NE, SENE, E2SE 50170-00 USA W-10681 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 E2NE, NESE, NWSE, S2SE, W2NE T029N R113W SEC-0026 NWNW T029N R113W SEC-0027 N2NE 50171-00 USA W-10682 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 NW, N2SW, S2SW T029N R113W SEC-0024 E2SE, NENW, NWNW, NWSE, SENW, SW, SWMW, SWSE, S2NE T029N R113W SEC-0025 NENW T029N R113W SEC-0027 NENW PAGE 7 50172-00 CHARLES P NOBLE ET UX 02/03/1954 BK 7 PG 360 WY SUBLETTE T029N R113W SEC-0011 E2NW, NE T029N R113W SEC-0012 W2NW 50173-00 USA EV-024549-A 07/01/1951 BK 22 PG 137 WY LINCOLN T026N R112W SEC-0005 THAT PORTION OF THE GREEN RIVER RIPARIAN TO LOTS 4, 5, 6, 7, 10, 11 AND 13 T026N R112W SEC-0008 THAT PORTION OF THE GREEN REIVER RIPARIAN TO LOTS 1, 2, 4, 5, 6, 7 AND 11 50174-00 USA W-20951 09/01/1947 BK9PR PG 66 WY LINCOLN T026N R112W SEC-0004 LOTS 1, 2, 3, 4, S2N2, SW4 50175-00 USA EV-022929-A 09/01/1952 BK9PR PG 206 WY SUBLETTE T027N R112W SEC-0033 NW4 50176-00 USA W-022931 11/01/1947 BK24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOTS 4 (17.01), 7 (7.50), 10 (25.29), 11 (42.73), 13 (23.59) AND SWSE T026N R112W SEC-0008 LOT 1 (12.18), 2, (19.72), 4 (32.67), 5 (20.41), 6 (18.10), AND W2NE LOT 7 (43.63), 11 (30.54) BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0029 LOTS 2 (35.76), 3 (16.18), 4 (45.23), 5 (6.90), 8 (6.23), 9 (37.63), 10 (1.67), 11 (22.05), 12 (23.76) 50177-00 USA EV-022931-A 11/01/1947 BK24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOT 1 (36.87), SENE, E2SE T026N R112W SEC-0008 E2NE, E2SE BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0028 ALL T027N R112W SEC-0029 E2SE T027N R112W SEC-0032 SENE, E2SE, NENE 50178-00 USA EV-022935 10/01/1947 BK 43 PG 242 WY LINCOLN T026N R112W SEC-0005 LOTS 5 AND 6 50180-00 USA EV-023229-A 07/01/1947 BK 89 PG 52 WY SUBLETTE T027N R112W SEC-0021 LOTS 9, 10, 11, SWSW PAGE 8 50181-00 USA W-20950 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0033 SE, NE4 T026N R112W SEC-0008 E2NE, E2SE 50182-00 USA W-039163 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0029 THAT PORTION OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 3, 4, 5, 8, 9, 10, 11, 12 50183-01 KENNETH BARLETT, GUARDIAN 10/29/1958 BK 22 PG 349 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-02 ATHOL L STOTTS, ET UX 01/23/1956 BK 15 PG 79 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-03 MARY MAXINE DELANEY, ET AL 01/23/1956 BK 15 PG 231 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50183-04 FLORENCE VICKREY, ET AL 01/23/1956 BK 15 PG 295 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50184-01 SELMER G LARSON, RECEIVER 06/21/1956 BK 18 PG 216 WY LINCOLN T026N R112W SEC-0008 LOTS 8 (16.37), 9 (28.05), 10 (41.40), SWSW 50184-02 WILLIAM J MCGINNIS 06/21/1956 BK 18 PG 214 WY LINCOLN T026N R112W SEC-0008 LOTS 8, 9, 10, SW4SW4, BED OF GREEN RIVER RIPARIAN TO LOTS 8, 9, & 10 50185-00 BENEFICIAL OIL CO. 09/16/1959 BK 24 PG 537 WY SUBLETTE T027N R112W SEC-0017 N2NE, SENE, NENW T027N R112W SEC-0020 LOTS 1, 2 & 5, NENE, NWSE T027N R112W SEC-0021 LOTS 2 (16.93), 3 (39.25), 4 (11.04), 5 (15.73), 6 (20.24), NWNW 50186-00 M F WHELAN LIVESTOCK COMPANY 01/25/1954 BK 9 PG 63 WY SUBLETTE T027N R112W SEC-0029 INSOFAR AS LSE COVERS: LOT 7 (NW/4SE/4) T027N R112W SEC-0032 INSOFAR AS LSE COVERS: NWNE, INCLUDING RIPARIAN RIGHTS IN THE GREEN RIVER 50187-00 USA W-06206 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 E2 T030N R113W SEC-0015 N2NW, NWNE, S2N2, NENE, N2S2, SESW, S2SE 50198-00 USA W-10678 10/01/1950 BK 31 PG 213 WY SUBLETTE PAGE 9 T029N R113W SEC-0025 S/2NE, N/2SE, SESE 50213-00 USA W-23002 03/01/1970 BK 58 PG 661 WY SUBLETTE T030N R113W SEC-0008 SESW, NESW, SWSW T030N R113W SEC-0017 NW, SW 50269-00 USA W-0322521 03/01/1966 BK294 PG 638 WY LINCOLN T026N R113W SEC-0009 SESW 50270-00 ST WY 63-11625 08/02/1963 BK204 PG 257 WY LINCOLN T026N R113W SEC-0016 ALL 50272-00 USA W-09156B 06/01/1948 BK 17 PG 283 WY LINCOLN T026N R113W SEC-0008 NE, N2SE, SESE, E2NW T026N R113W SEC-0009 W2W2M E2NW, NESW 50274-00 USA W-020123-A 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0004 SWSW T027N R112W SEC-0005 SESE, LOT 4, S2NW, SW, N2SE, W2SE T027N R112W SEC-0009 SWSW T027N R112W SEC-0017 SE, SWNE T027N R112W SEC-0029 W2NE 50275-00 USA W-025407A 05/01/1954 BK 34 PG 635 WY SUBLETTE T027N R112W SEC-0031 LOTS 1, 2, 5, 6, 7, 8, 11, 12, E2NWNE, W2NWNE T030N R113W SEC-0017 NW, SW 50276-00 USA W-020123 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0006 ALL T027N R112W SEC-0008 W2NW, SENW, SW T027N R112W SEC-0020 LOT 6, NW, N2SW, SWSW 50277-00 USA EV-023313 02/01/1948 BK286 PG 640 WY LINCOLN T026N R112W SEC-0006 SWNE 50278-00 USA EV-023313 02/01/1948 BKK286 PG 640 WY LINCOLN T026N R112W SEC-0006 SESW, NESW, SWSW PAGE 10 50279-00 USA W-024793 02/01/1954 BK 30 PG 138 WY LINCOLN T026N R113W SEC-0014 SENW, SW T026N R113W SEC-0022 NENE, SENE, SENW, SWNE T026N R113W SEC-0023 N2NW, LOTS 1, 2, 3, 4 50280-00 USA W-022407 05/01/1954 BK150 PG 334 WY SUBLETTE T027N R112W SEC-0006 LOTS 3, 4, 7, 8, NENE, W2NE, NWSE, N2SWSE, SESWSE, SWSWSE 50281-00 USA W-025410 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0030 LOTS 1, 2, 5, 6, E2W2 BK 30 PG 490 WY LINCOLN T027N R112W SEC-0002 LOT 1 50282-00 USA W-025410-A 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0031 LOTS 3, 4, 7, 9, NWNENW, W2SE, S2SWNE, NESWNE LOT 10, E2NENW, SWNENW, SENW, NWSWNE, E2SW 50283-00 USA EV-025440 03/01/1950 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0007 NE, W2SE, E2SE T027N R112W SEC-0018 S2NE, SE, N2NE 50284-00 USA EV-025440-A 03/01/1955 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0019 E2 50285-00 USA W-033951 07/01/1955 BK 296 PG 257 WY SUBLETTE T026N R113W SEC-0010 S2NE 50286-00 USA W-036054 04/01/1956 BK 21 PG 292 WY SUBLETTE T027N R113W SEC-0027 NWNE 50287-00 USA W-038682 09/01/1956 BK 288 PG 52 WY LINCOLN T026N R113W SEC-0002 LOTS 2, 3, 5, 6, 12 BK 70 PG 151 WY SUBLETTE T027N R113W SEC-0035 W/2 50288-00 USA W-03682-A 09/01/1956 BK 88 PG 52 WY LINCOLN T026N R113W SEC-0014 LOTS 3, 4 PAGE 11 50290-00 USA W-047412 09/01/1958 BK 88 PG 123 WY SUBLETTE T027N R112W SEC-0009 LOT 1 50291-00 USA W-0499597412 06/01/1957 BK 23 PG 512 WY LINCOLN T026N R112W SEC-0006 THAT PORTION OF THE BED OF GREEN RIVER RIPARIAN TO LOT 7 50292-00 USA W-050961 09/01/1957 BK 24 PG 335 WY LINCOLN TO26N R112W SEC-0006 LANDS COVERING ALL OF THE BED OF THE GREEN FIVER LYING IN LOT 6 BETWEEN THE MEAN HIGH WATER MARKS THEREOF, EXCEPTING THAT PORTION OF THE SAID RIVER BED WHICH LIES RIPARIAN TO LOT 7 OF SEC 6. SAID LANDS BEING ONLY THAT PORTION OF THE BED OF THE GREEN RIVER APPURTENANT TO LOT 6. 50293-00 USA W-052064 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0007 LOT 5 T026N R112W SEC-0018 LOT 1, 2, 3, PAGE 12 50294-00 USA W-052065 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0006 LOT 1, 2, 3, 4, 5, 6, 7, 9 50295-00 USA W-05751 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0007 LOTS 1, 2, 3, 4, E2W2 T027N R112W SEC-0018 LOT 1, 2, E2NW, LOTS 3, 4, E2SW 50296-00 USA W-05751-A 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0019 LOT 1, 2, 3, 4, E2W2 50297-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0030 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 4, 7, 8 50298-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0031 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, 5, 6, 7, 8 11, 12 50299-00 USA W-059585 07/01/1947 BK 85 PG 49 WY SUBLETTE T027N R112W SEC-0009 LOTS 2 (6.59), 3 (10.11) T027N R112W SEC-0020 LOTS 3, (4.94), 4 (20.40) 50300-00 USA W-066369 07/01/1988 BK305 PG 26 WY LINCOLN T026N R113W SEC-0015 S/2 50301-00 USA W-066370 10/11/1958 BK305 PG 30 WY LINCOLN PAGE 12 T026N R112W SEC-0022 N2NW, NWNE, SWNW, NWSW 50302-00 USA EV-07798-E 09/01/1954 BK 30 PG 22 WY LINCOLN T026N R113W SEC-0002 LOT 4 (41.5) T026N R113W SEC-0010 SE T026N R113W SEC-0011 N2NW, SENW, SW, W2NE, W2SE, LOTS 1, 2, 3, 4 T026N R113W SEC-0014 N2NW, SWNW, W2NE, W2SE, LOTS 1, 2 T026N R113W SEC-0015 N2N2 50303-00 USA EV-08051-B 04/01/1958 BK 86 PG 278 WY SUBLETTE T027N R113W SEC-0027 E2NE, E2SWNE 50304-00 ST WY 0-11135 05/16/1951 BK 22 PG 430 WY LINCOLN T026N R113W SEC-0013 ALL (RES PT LOT 37) 50305-00 ST WY 0-1137 05/16/1951 BK 22 PG 433 WY LINCOLN T026N R113W SEC-0024 S2N2 (RES LOT 39) 50306-00 ST WY 0-11141E 05/16/1951 BK 21 PG 272 WY SUBLETTE T027N R113W SEC-0036 ALL 50307-00 ANDERSON L MCGINNIS, ET UX 12/26/1956 BK 16 PG 336 WY SUBLETTE T027N R112W SEC-0003 PARTS OF LOTS 3 & 4 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT ON THE EAST LINE OF SAID LOT 3, 325' SOUTH OF THE OLD PARTITION FENCE, THENCE ALONG SAID FENCE 89 DEGREES WEST TO THE WEST BOUNDARY OF SAID LOT 4, THENCE SOUTH TO THE SW CORNER OF SAID LOT 4, THENCE EAST TO THE SE CORNER OF SAID LOT 3, THENCE NORTH TO THE PLACE OF BEGINNING. THAT PART OF LOT 5 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT 1635' SOUTH OF THE QUARTER SECTION CORNER ON THE NORTH LINE OF SAID SECTION AND RUNNING THENCE EAST ALONG THE MCGINNIS MICKELSON PARTITION FENCE TO THE GREEN RIVER, THENCE IN A SOUTHEASTERLY DIRECTION ALONG GREEN RIVER TO THE EAST AND WEST QUARTER SECTION LINE IN SAID SECTION 3, THENCE WESTERLY ALONG SAID EAST AND WEST QUARTER SECTION LINE TO THE CENTER OF SAID SECTION 3, THENCE NORTH TO THE PLACE OF BEGINNING. E2SW, NWSW, SWSW, S2NW, LOTS 8 & 9 T027N R112W SEC-0004 SE, SESW, S2NE, LOT 1 T027N R112W SEC-0008 E2NE T027N R112W SEC-0009 NW, N2NE, N2SW, SESW, SWNE, S2SE, LOTS 1, 4, 5 PAGE 13 T027N R1112W SEC-0010 LOTS 2, 3, 7 50308-00 ST WY 0-11134 05/16/1951 BK 22 PG 439 WY LINCOLN T026N R113W SEC-0012 ALL 50309-01 SELMER G LARSON 01/08/1957 BK 20 PG 434 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, W2, SE T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, NESW, NE4, N2SE4 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW 50309-02 NEWT SIMS LARSON 12/15/1956 BK 20 PG 234 WY LINCOLN T026N R112W SEC-0017 S2S2 T026N R112W SEC-0018 PART SESE E OF HWY 189 T026N R112W SEC-0019 PART E2NE, NESE E HWY 189 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW, LOTS 2, 3, 6 50309-03 WILLIAM J MCGINNIS ET UX 11/13/1956 BK 19 PG 394 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, N2SE, NW, N2SW T026N R112W SEC-0018 W2NE, E2NW, NESW, SESW, LOT 4, SWSE, NE4, N2SE T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, W2NE, NESW, NWSE, ALSO ALL THAT PART OF THE SE4SE4 SEC 18; E2NE4, NE4SE4, SEC. 19 LYING WEST OF STATE HWY 287, CENTER LOCATION OF SAID HWY BEING LOCATED IN SAID SE4SE4, SECTION 18 AND E2NE4, NE4SE4, SEC. 19 AS FOLLOWS: 958 FEET WEST OF NE CORNER OF SE4SE5, SEC. 18; 701 FEET WEST OF NE CORNER, SEC. 19; 554 FEET WEST OF EAST SECTION LINE ALONG THE HALF SECTION LINE OF SEC. 19; AND 177 FEET WEST OF SE CORNER OF SEC. 19, CONTAINING 1,375.10 ACRES, MORE OR LESS. 50310-00 ST WY 0-11216B 05/16/1951 BK 3 PG 468 WY SUBLETTE T027N R112W SEC-0016 W2 50311-00 USA W-048781 06/01/1956 BK 24 PG 339 WY SUBLETTE T0276N R113W SEC-0035 E/2 PAGE 14 50312-00 ST WY 0-11136 05/16/1951 BK 22 PG 436 WY LINCOLN T026N R112W SEC-0024 N2N2 (RES LOT 38) NWSW (RES LOT 40) 50318-00 GEORGE E YEAMAN ET UX 11/29/1956 BK 20 PG 248 WY LINCOLN T026N R112W SEC-0007 W2NE, NENE, LOT 3 T026N R112W SEC-0008 LOT 3, EXCEPT HWY TRACT 50319-00 WINSTON H ALLEMAN ET UX 02/26/1959 BK 32 PG 445 WY LINCOLN T026N R112W SEC-0005 LOT 12 T026N R112W SEC-0006 THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLAT NO. 1 FOR SW4SE4 AND NW4SE4 SECTION 6-26-112 LINCOLN COUNT LOT 2: ALL LINCOLN COUNT LOT 3: ALL LINCOLN COUNTY LOT 8: ALL, EXCEPT FOR THE FOLLOWING DESCRIBED PARCELS: BEGINNING AT THE SOUTH WEST CORNER OF THE SOUTH WEST QUARTER OF THE SOUTH EAST QUARTER (SW4SE4) OF SECTION SIX THENCE EAST ON THE SECTION LINE BETWEEN SAID SECTIONS SIX (6) AND SEVEN(7), TOWNSHIP TWENTY-SIX NORTH, RANGE ONE HUNDRED TWELVE WEST OF THE 6TH P.M. IN WYOMING, A DISTANCE OF 1043.35 FEET; THENCE NORTH A DISTANCE OF 835 FEET; THENCE WEST A DISTANCE OF 1043.35 FEET; THENCE SOUTH ON THE MID-SECTION LINE OF SAID SECTION SIX A DISTANCE OF 835 FEET TO THE POINT OF BEGINNING. TWO AND NINETY SEVEN HUNDREDTHS ACRES MORE OR LESS, STARTING FROM A POINT 1043.35 FEET EAST AND 835 FEET NORTH OF THE SOUTH WEST CORNER OF LINCOLN COUNTY, LOT NUMBER 8 AS SHOWN UPON LINCOLN COUNTY METES AND BOUNDS MAP NUMBER ONE, SECTION 6, TOWNSHIP 26 NORTH, RANGE 112 WEST; THENCE IN A NORTHERLY DIRECTION PARALLEL TO THE WEST BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 TO THE NORTH BOUNDARY OF SAID LOT 8; THENCE WEST ALONG THE NORTH BOUNDARY LINE OF SAID LOT NUMBER 8 TO THE CORNER THAT IS 566.31 FEET FROM ITS WESTERN BOUNDARY, THENCE IN A SOUTHERLY DIRECTION PARALLEL TO THE WESTERN BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 FOR A DISTANCE OF 271.35 FEE; THENCE IN AN EASTERLY DIRECTION TO THE POINT OF BEGINNING. LINCOLN COUNTY LOT 21: ALL LA BARGE TOWN LOTS 5-12; INCLUSIVE IN BLOCK 1 51% OF LOTS 1 & 2, AND ALL OF LOTS 5-20, INCLUSIVE IN BLOCKS 3 OF THE SECOND ADDITION AND LOT 23, BLOCK 1 OF THE ORIGINAL TOWNSITE. THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLATE NO. 2, FOR LOTS 8 & 11, SECTION 6-26-112 PAGE 15 LINCOLN COUNTY LOT 19: ALL LINCOLN COUNTY LOT 20: ALL 50320-01 CYRIL HOUSLEY ET UX 11/14/1956 BK 19 PG 398 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, NWSE, SENW, NESW 50320-02 AUGUSTA B MARX 11/19/1956 BK 19 PG 475 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, SENW, NWSE, NESW 50322-00 ST WY 0-22646T UX 11/16/1958 BK 35 PG 543 WY LINCOLN T026N R112W SEC-0001 ALL OF ORIGINAL SECTION 1 50324-00 JOHN E MARX ET UX 11/01/1956 BK 19 PG 353 WY LINCOLN T026N R112W SEC-0006 E2SW, LOT 10 T026N R112W SEC-0007 LOT 1, NENW 50325-00 USA W-033913 11/01/1956 BK 22 PG 419 WY SUBLETTE T028N R112W SEC-0033 W2NW, NWSE, NENE, S2NE, E2NW, NWNE, SWSE, E2SE 50329-01 WY STATE HWY COMMISSION 08/22/1958 BK 32 PG 379 WY LINCOLN T026N R112W SEC-0006 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 1: E2SE PARCEL 2: LOT 11, SWSE T026N R112W SEC-0007 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 3: E2NE PARCEL 4: E2SE PARCEL 5: E2SE, SWSE PARCEL 6: NWSE PARCEL 7: LOT 3, NENE, W2NE PARCEL 8: W2NE PARCEL 9: NENW, LOT 1 PARCEL 10: PARCEL OF LAND INCLUDED WITHIN THE RIGHT OF WAY OF THE STAT HIGHWAY PROJECT L. N. -10 & F.A. PROJECT 158A, KNOWN AS THE KEMMERER-MARBLETON ROAD, SAID RIGHT-OF- WAY BEING 80' WIDE AND LYING 40' ON EITHER SIDE AND BEING EQUIDISTANT FROM A CERTAIN CENTER LINE DESCRIBED BY COURSES AND DISTANCES AS FOLLOWS: BEGINNING AT A POINT DESIGNATED IN THE FIELD NOTES OF THE SURVEY OF THE ABOVE MENTIONED HIGHWAY AS STATION 1276 40.0, SAID POINT BEING ON THE SOUTH BOUNDARY LINE OF NESE OF SECTION 19-26N-112W, 6TH P.M.; AND N 17 DEGREE 11' W A DISTANCE OF 1129.9' FROM POINT WHICH IS N 31 DEGREE 48' W A DISTANCE OF 337.3' FROM A POINT WHICH IS EAST A DISTANCE OF 250' FROM THE SE CORNER OF SECTION 19, AFORESAID; THENCE N 17 DEGREE 11' W A DISTANCE OF 1076.2' TO A POINT OF AN 8 DEGREE 00' CURVE TO PAGE 16 THE RIGHT, THE RADIUS OF WHICH IS 716.2', THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 16 DEGREE 00', A DISTANCE OF 200'; THENCE N 1 DEGREE 11; W A DISTANCE OF 2142.3'; THENCE N 1 DEGREE 21' E 145.2' TO POINT OF A 10 DEGREE 00' CURVE TO THE LEFT, THE RADIUS OF WHICH IS 573'; ALONG SAID CURVE THROUGH AN ANGLE OF 21 DEGREE 40' A DISTANCE OF 216.7; THENCE N 20 DEGREE 19' W A DISTANCE OF 484.3" TO A POINT OF A 6 DEGREE 00' CURE TO THE RIGHT, THE RADIUS OF WHICH IS 954.9'; THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 11 DEGREE 23' A DISTANCE OF 189.7; THENCE N 8 DEGREE 56' W A DISTANCE OF 2582.7' TO THE POINT OF A 5 DEGREE 00' CURVE TO THE RIGHT, THE RADIUS OF WHICH IS 1145.9'; THENCE ALONG SAID CURVE, THROUGH AN ANGLE OF 9 DEGREE 11' A DISTANCE OF 183.7'; THENCE N 0 DEGREE 15' E A DISTANCE OF 4889.2, THE END, WHICH IS STATION 1397 50 OF SAID SURVEY, WHICH POINT IS ON THE E & W CENTER LINE OF SECTION 7, 26N-112W OF THE 6TH P.M. T026N R112W SEC-0018 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: E2SE, E2NE PARCEL 5: NE T026N R112W SEC-0019 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NESE, E2NE PARCEL 5: NENE PARCEL 10: SEE METES AND BOUNDS DESCRIBED IN SECTION 7 T026N R112W SEC-0020 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NWSW 50343-00 USA W 05749 05/01/1951 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0010 LOT 1, NENE, S2NE T027N R112W SEC-0011 NE T027N R112W SEC-0012 S2N2, SE T027N R112W SEC-0013 E2 50344-00 USA W-066702 07/01/1947 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 LOT 4 AND 5 50346-00 USA W-278782 04/01/1971 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0001 SE PAGE 17 T027N R112W SEC-0012 N2NE 50347-00 USA EV-023053 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2NE 50348-00 USA EV-023053-A 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2SE 50349-00 USA EV-023057 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0010 SE T027N R112W SEC-0015 W2NE 50350-00 USA EV-023057-A 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0015 W2SE 50351-00 USA EV-023066 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0010 E2SW, LOTS 6, 8 T027N R112W SEC-0015 E2NW, SWNW, LOT 1 50352-00 USA EV-023066-A 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0015 SW 50353-00 USA W-053031 09/01/1957 BK 87 PG 702 WY SUBLETTE T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER RIPARIAN TO LOT 2 MORE FULLY DESC. BY METES & BOUNDS IN LSE. 50354-00 USA W-066701 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 4, 5, 6, 8 T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOT 1 ALL ACRES SHOWN IN SEC 10 50355-00 USA W-07828 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R112W SEC-0003 LOTS 7 (NENW), 8 (NWNW), S2NW, N2SW 50362-00 USA W-01332 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 SESE, SWSE, N2SE, S2NE, SENW 50365-00 USA EV-013494 12/31/1938 BK 31 PG 333 WY SUBLETTE T029N R113W SEC-0014 SW, W2SE, S2NW, SWNE T029N R113W SEC-0023 E2 50380-00 USA W-60577 11/01/1977 BK 73 PG 208 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1, 2, 3, 4, E2, E2W2 PAGE 18 T028N R111W SEC-0031 NE, E2SE T027N R111W SEC-0032 W2 50384-00 USA W-62791 05/01/1978 BK 65 PG 556 WY SUBLETTE T028N R111W SEC-0025 E2 LOT 1 (20.64 AC) LOT 3 (41.1 AC) 40.82 AC) LOT 6 (30.22 AC) LOT 7 (40.54 AC), SESWNE, SENESW, SESW, W2SE T028N R111W SEC-0031 LOTS 1 (NWNW), 2(SWNW), E2NW, W/2SE LOTS 3 (NWSW), 4 (SWSW), E2SW 50431-00 USA EV-022769-A 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0001 LOTS 3, 4, S2NW, SW T029N R113W SEC-0002 LOTS 1, 2, 3, 4, S2NE SENW, S2 50432-00 USA EV-0177710-B 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0028 E2 T030N R113W SEC-0034 N2SW, SE, SESW 50434-00 USA EV-017710-A 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0034 SWSW 50435-00 USA EV-022769 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0003 LOTS 1 32.83), 2 (32.18) 3 (31.53), 4 (30.88) S/2N/2, SW, S/2SE, NWSE T029N R113W SEC-0004 LOTS 1 (31.11), 2(32.20)M 3 (33.30), S/2NE, SENW, NESW, N/2SE T030N R113W SEC-0033 E/2, E/2W/2 55787-01 KATHLEEN ANN MILLER 08/31/1986 BK 77 PG 548 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-02 ROBERT M MILLER JR ET UX 08/13/1986 BK 77 PG 554 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-03 MATTHEW DANIEL MILLER 08/13/1986 BK 77 PG 550 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-04 PATRICIA M ROBERTS ET VIR 08/13/1986 BK 77 PG 552 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-05 PRISCILLA KYSAR ET VIR 08/13/1986 BK 77 PG 546 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-06 ALBERT E SCHWABACHER ET AL 04/13/1988 BK 81 PG 655 WY SUBLETTE T029N R113W SEC-0011 W2NW 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW PAGE 19 T029N R113W SEC-0003 NESE 57790-00 USA W-01763 03/01/1986 BK274 PG 531 WY LINCOLN T029N R112W SEC-0013 LOTS 1 & 2 57808-00 USA EV-026240 11/01/1950 BK305 PG 95 WY LINCOLN T026N R113W SEC-0023 NWNE 57809-00 USA W-059091 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, & 3 T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 3 & 4 57810-00 USA W-025765 06/01/1954 BK305 PG 89 WY LINCOLN T0276 R112W SEC-0002 LOTS 7, 8, 9, 10, & 11 57821-00 JOSEPH W KRALL 03/23/1989 BK 82 PG 551 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/SW 57821-02 SUSAN K DONALDSON ET VIR 03/23/1989 BK 82 PG 643 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-03 SALLY ORR, ET VIR 03/23/1989 BK 82 PG 641 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-04 JUDY BETKA, ET VIR 03/23/1989 BK 82 PG 645 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-05 NANCY JO T KNADLER, ET VIR 03/22/1989 BK 82 PG 549 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-06 TED E MILLER 03/29/1989 BK 82 PG 635 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-07 FRANK T MILLER 03/29/1989 BK 82 PG 637 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-08 MARILYN JAMES, ET VIR 03/31/1989 BK 82 PG 639 WY SUBLETTE T027N R113W SEC-0032 SESE PAGE 20 T027N R113W SEC-0033 S/2SW 57964-00 USA WYW-034923 10/01/1950 BK314 PG 254 WY LINCOLN T0267N R113W SEC-0008 SWSE 75007-00 USA WY-088276 07/01/1961 BK 50 PG 61 WY LINCOLN T026N R113W SEC-0011 SWNW 75012-00 USA EV-021976 04/01/1949 BK 18 PG 130 WY LINCOLN T026N R113W SEC-0005 LOT 3, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 6, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75013-00 USA EV-025792 09/01/1946 BK314 PG 218 WY LINCOLN T026N R113W SEC-0005 LOT 1, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 7, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 8, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 PAGE 21 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75021-00 USA W-104985 08/01/1987 BK263 PG 159 WY LINCOLN T026N R111N SEC-0008 N2NW, SENW 75022-00 USA WYW-102101 11/01/1986 BK263 PG 163 WY LINCOLN T026N R111N SEC-0008 N2NW, SWNW, SWSW T026N R111N SEC-0022 SWNW, S2 T026N R111N SEC-0028 NENE 75047-00 USA WYW-11667 12/01/1988 BK314 PG 241 WY LINCOLN T026N R114W SEC-0011 NE, S2 T025N R114W SEC-0012 LOTS 1-12, W/2 T025N R114W SEC-0013 LOTS 1-12, W/2 75052-00 CARL TAYLOR, ET UX 04/22/1959 BK 34 PG 187 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS: BLOCK 1: LOTS 3 & 19 = .13774 AC BLOCK 3: LOTS 1, 2, 3, 4, 8, 9, 10, 11 AND 12 = .61983 AC PAGE 22 BLOCK 12: LOTS 1,2,3,4,5,6,7, AND 8 -.55096 ACRES 75054-00 C J PAYNE, ET UX 03/07/1959 BK 34 PG 183 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 27,28,29 BLOCK 5: LOTS 15,16 BLOCK 7: LOT 15 CONTAINING .41322 ACRES 75055-00 JAMES A DEGRAW, ET UX 03/07/1959 BK 34 PG 181 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOTS 6,7,8,9,10 BLOCK 11: LOT 1 CONTAINING .41322 ACRES 75056-00 CECIL J STUDT, ET UX 03/07/1959 BK 34 PG 179 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK A: RIVER VIEW ADDITION LOT 3 BLOCK C: RIVER VIEW ADDITION LOTS 1,2,3,4,5,6,7,8 BLOCK 5: LOTS 1,2,3,4,5,6,7,8,17,18,19,20,21,22,23 CONTAINING 1.65309 ACRES 75057-00 CYRIL HOUSLEY, ET UX 03/07/1959 BK 34 PG 177 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS SECOND ADDITION, BLOCK 1: LOTS 3 AND 4 CONTAINING .289254 ACRES 75058-01 THERESA R DECKER 03/07/1959 BK 34 PG 175 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 3 & 4 BLOCK 6: SOUTHERLY 8 FEET OF LOT 2 75059-00 WM R DEGRAW, ET UX 03/12/1959 BK 34 PG173 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 13 & 14 CONTAINING .13774 ACRES 75060-00 ROBERT A DEGRAW, ET UX 03/12/1959 BK 34 PG 171 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 10: LOTS 1,2,3 CONTAINING .20661 ACRES 75061-00 MARIE F IVERSON 03/12/1959 BK 34 PG 169 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 23,24,25, AND 26 CONTAINING .27548 ACRES 75062-00 NEIL HACKLIN, ET UX 03/18/1959 BK 34 PG 167 WY LINCOLN PAGE 23 T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK B: LOTS 13,14,15, AND 16 = .27598 AC 75063-01 ELLIS E ALEXANDER, ET UX 03/18/1959 BK 34 PG 165 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 1,2,3,4,5,6, AND 7 CONTAINING .48209 ACRES 75063-02 FRANK ZAGAR, ET UX 07/15/1959 BK 41 PG 104 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 3,4,5,6, AND 7 75064-00 GERALD C HALE, ET UX 03/18/1959 BK 34 PG 163 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 27, 28, 29, 30, 31 AND 32 CONTAINING .41322 ACRES 75065-00 JOHN E GAULT, ET UX 03/20/1959 BK 34 PG 161 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 8,9, AND 10 CONTAINING .20661 ACRES 75066-00 JOHN EDLUND, ET UX 03/20/1959 BK 34 PG 159 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 8-10 .20661 ACS. BLOCK 10: LOTS 11-14 AND 16 .34435 ACS. 75067-00 WALTER J CRANOR, ET UX 03/20/1959 BK 34 PG 157 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 9-11 .20661 ACS. BLOCK 8: LOTS 11-15 .34435 ACS 75068-00 HOLGER JOHNSON, ET UX 03/20/1959 BK 34 PG 155 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 13-16 .27548 ACRES 75069-00 JESSE R GAULT, ET UX 03/21/1959 BK 34 PG 153 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 5,6,7, AND 8 CONTAINING .27548 ACRES 75070-00 PETE SUNDGREN, ET UX 03/23/1959 BK 34 PG 151 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 6,7 & 8; .20661 AC. 75071-00 NORMAN KIEFFER, ET UX 03/23/1959 BK 34 PG 149 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS PAGE 24 BLOCK 7: LOT 4 & 5; .13774 AC. 75072-00 ARVEL A DAVID, ET UX 03/23/1959 BK 34 PG 147 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 20-22 .20661 ACRES 75073-00 ERIC WALLIN 03/23/1959 BK 34 PG 145 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 12-13 .13774 ACS. 75074-00 JOHN PEARSON 03/23/1959 BK 34 PG 143 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOT 6 .06887 ACS. 75075-00 DONALD L STUDT, ET UX 03/23/1959 BK 34 PG 141 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOTS 7-11 .34435 ACS. 75076-00 GEORGE VICKREY, ET UX 03/25/1959 BK 34 PG 139 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 22-26 .34435 ACRES BLOCK 6: LOTS 18-19 .13774 ACRES BLOCK 7: LOTS 1-2 .13774 ACRES 75077-00 NELS OSTROM 03/26/1959 BK 34 PG 137 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 10 .06887 ACRES 75078-00 JOHN WESTERLUND 03/26/1959 BK 34 PG 135 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2, LOT 9 .06887 ACS. 75079-00 SAM OHME 03/26/1959 BK 34 PG 133 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 14; .06887 AC. 75080-00 RALPH V WHITE, ET UX 03/26/1959 BK 34 PG 131 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK E: LOTS 9,10,12,13; .309915 AC. 75081-00 CARL KULINSKY, ET UX 03/26/1959 BK 34 PG 127 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 1&2; .13774 AC. 75082-00 C E TALCOTT, JR, ET UX 03/26/1959 BK 34 PG 129 WY LINCOLN TO26N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS PAGE 25 BLOCK 5: LOT 26; .06887 AC. 75083-00 OLIVER E GREGORY, ET UX 03/30/1959 BK 34 PG 125 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOTS 8,9,10,24,25; .34435 AC. 75084-00 J. THOMAS HALL, ET UX 03/30/1959 BK 34 PG 123 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 27,28 & 29; .20661 AC. 75085-00 PETE M GOLICH, ET UX 03/30/1959 BK 34 PG 121 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1, LOTS 1 AND 2 .13774 ACS. 75086-00 VINCENT A GUYETTE 03/30/1959 BK 34 PG 105 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK B LOTS 11 & 12 .13774 ACS. 75087-00 AARON NEALE JONES, ET UX 03/26/1959 BK 34 PG 119 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK D LOTS 1,2,3,4 .27548 ACS 75088-00 ALVIN VALLETT, ET UX 04/02/1959 BK 34 PG 117 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 2,3,4; .20661 AC. 75089-01 LESLIE C VASEY, ET UX 04/06/1959 BK 34 PG 115 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 3; .06887 AC SECOND ADDITION, BLOCK 3: LOTS 1 & 2; 1.61 AC. 75090-00 SCHOOL DISTRICT NO. 1 04/13/1959 BK 34 PG 113 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 1,2,3,4,5,6,7; .48209 AC. 75091-00 VIRGIL V BAILEY, ET UX 03/07/1959 BK 34 PG 97 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOT 14; .06887 AC. BLOCK 6: LOTS 5,6,7,8,9 AND 10; .41322 AC. BLOCK 7: LOT 16; .06887 AC. 75092-00 DON WAGNER, ET UX 04/20/1959 BK 34 PG 111 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 30, 31 & 32; .20661 AC. 75093-00 JIMMY DE GRAW, ET UX 04/06/1959 BK 33 PG 419 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS PAGE 26 RIVER VIEW ADDITION BLOCK D: LOTS 5 & 6; .13774 AC. 75094-00 VELMA WILSON, ET AL 04/20/1959 BK 34 PG 109 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 11; .06887 AC. 75095-00 HERMAN PIZ, ET AL 04/22/1959 BK 34 PG 107 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 3; LOTS 13 & 14; .41322 AC. 75096-00 GORDON GUYETTE, ET UX 06/02/1959 BK 34 PG 103 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK D: LOT 7; .06887 AC. 75097-00 ALEX J BERTAGNOLLI 05/09/1959 BK 34 PG 99 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 1,2,3,17,18,19,20 & 21; .55096 AC. 75098-00 PAUL I BERTAGNOLLI, ET UX 06/04/1959 BK 34 PG 101 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 4 & 5; .13774 AC. 75099-01 C.J. YATES 10/31/1959 BK 41 PG 98 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOT 26 75100-00 LEO MANSKE, ET UX 10/12/1959 BK 41 PG 100 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 12,13,14 & 16 75110-00 USA WYW-124999 10/01/1991 BK303 PG 145 WY LINCOLN T025N R112W SEC-0022 ALL 75148-00 USA WYW-125960 01/01/1992 BK314 PG 43 WY LINCOLN TO25N R112W SEC-0024 LOT 1 75158-00 USA WY-42788 01/01/1974 BK314 PG 223 WY LINCOLN TO25N R112W SEC-0024 W2NE, W2SE, LOTS 2,3,4 T025N R112W SEC-0025 N2NW, SENW, SW, SWNW, W2NE, W2SE, LOTS 1,2,3,4 75174-00 USA EV-07675(C) 11/01/1965 BK 88 PG 535 WY SUBLETTE T027N R113W SEC-0034 E2E2 BK311 PG 679 WY LINCOLN T026N R113W SEC-0003 LOT 1 PAGE 27 75175-00 USA EV-07798(C) 09/01/1964 BK311 PG 221 WY LINCOLN T026N R113W SEC-0003 SWSE T026N R113W SEC-0010 W2SW 75176-00 USA EV-07798(D) 09/01/1964 BK311 PG 226 WY LINCOLN TO26N R113W SEC-0003 E2SE, LOTS 8 AND 9 T026N R113W SEC-0010 E2SW, N2NE 75177-00 USA EV-08051(A) 02/01/1948 BK 88 PG 511 WY SUBLETTE T027N R113W SEC-0027 NENW, W2SWNE 75178-00 USA EV-024168 11/01/1947 BK 36 PG 108 WY SUBLETTE T027N R113W SEC-0027 NWSE 75179-00 USA WY-040934 06/01/1956 BK 36 PG 222 WY SUBLETTE T027N R113W SEC-0027 NESE 75180-00 USA WY-041447 06/01/1956 BK 36 PG 227 WY SUBLETTE TO27N R113W SEC-0027 SESE 75181-00 USA WY-088274 07/01/1961 BK 50 PG 67 WY LINCOLN T026N R113W SEC-0002 SW 75182-00 USA WY-088275 07/01/1961 BK 50 PG 64 WY LINCOLN T026N R113W SEC-0002 W2SE, LOTS 13, 14 PAGE 28 50002-00 ENGER K CHRISMAN 06/18/1947 BK 5 PG 3 WY SUBLETTE T029N R113W SEC-0010 SENE, NWSE 50004-00 USA W-10676 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0013 W/2 SW/4 S/2 NW/4, SW/4 NE/4, NE/4 SW/4 T029N R113W SEC-0023 W/2 W/2 50012-00 CLIFTON FEAR, ET AL 04/12/1955 BK 11 PG 449 WY SUBLETTE T029N R113W SEC-0009 E2SW, SE T029N R113W SEC-0010 SWNW, SWSE, SW T029N R113W SEC-0015 N2N2 50023-00 USA W-05689 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 W/2SWSW, E/2SWSW, SESW 50025-00 USA W-17208 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0032 LOTS: NE PART OF 17, 18, 19, 20 ALL LOT 17 EXCEPT NE 50030-00 USA W-21124 06/01/1951 BK 34 PG 174 WY SUBLETTE T030N R113W SEC-0004 LOTS 3, 4 T030N R113W SEC-0005 LOT 1, SENE, SW LOTS 2,3,4, SWNE, S2NW T030N R113W SEC-0006 SENE, NESE, LOTS 1,2, SWNE 50032-00 USA W-02736 12/01/1950 BK 33 PG 343 WY SUBLETTE T031N R113W SEC-0028 SWNW, NWSW T031N R113W SEC-0029 N2, SE, SW T031N R113W SEC-0031 E2NE, NESE LOTS 1-4, E2W2, W2NE, S2SE, NWSE T031N R113W SEC-0032 W2, W2SE, E2E2, W2NE T031N R113W SEC-0033 NWNW, S2NW, SW, SWNE, SE 50034-00 USA W-05958 07/01/1951 BK PG WY LINCOLN T025N R113W SEC-0031 S2 LOT 3, LOT 4, W2 LOT 5, SWNESW N2 LOT 3, E2 LOT 5, N2NESW, SENESW 50035-00 EDGAR F HERSCHLER ET UX 09/19/1953 BK 5 PG 398 WY LINCOLN T024N R114W SEC-0000 RESURVEY TRACT 50 BEING THE WEST 3/4 AND RESURVEY TRACT 55 BEING ALL PAGE 29 RESURVEY TRACT 49 BEING THE WEST 40 ACRES 50036-00 ARNOLD A LARSON ET UX 09/18/1953 BK 5 PG 361 WY LINCOLN T024N R114W SEC-0000 TRACT 46-B (ORIGINALLY SESW SEC. 2) TRACT 45 BEING THE CENTER 1/3 (ORIGINALLY THE NWNW SEC. 11) TRACT 50 BEING THE MOST EASTERLY 1/4, ORIGINALLY SWNE SEC. 3 (42.79 AC) PORTION OF TRACT 48, ORIGINALLY SENE SEC. 3 (41.83 AC) TRACT 45 BEING THE MOST WESTERLY 1/3, ORIGINALLY NENE SEC. 10 TRACT 49 BEING THE MOST EASTERLY 80 ACRES, ORIGINALLY W2SE SEC. 3 T024N R114W SEC-0002 LOTS 16 (39.10), 17 (5.71), 18 (6.48) T024N R114W SEC-0003 LOTS 12 (22.51), 13 (20.35) LOTS 14 (17.84), 18 (17.84) 50037-00 ST WY 08945 09/16/1949 BK 5 PG 382 WY LINCOLN T025N R114W SEC-0036 SESE LOT 40, E2SWSE LOT 40 ALL LESS AND EXCEPT SESE LOT 40, E2SWSE LOT 40 50038-00 USA W-01902 03/01/1950 BK 10 PG 134 WY LINCOLN T024N R114W SEC-0003 W2 LOT 10 AND LOT 11, E2 LOT 10 50039-00 USA EV-024522-A 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 SESE 50040-00 USA EV-024521-A 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 SESE 50041-00 USA EV-024522 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0015 SENW, S2NE, SE, E2SW, N2N2, SWNW, E2SW T023N R112W SEC-0021 NE, N2SE, SWSE T023N R112W SEC-0028 NE 50042-00 USA EV-24521-B 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 N2, N2S2, S2SW, SWSE T023N R112W SEC-0023 NWNW, NE, NENW, S2NW, S2 T023N R112W SEC-0027 NW, N2NE 50059-00 CHAMPLIN PETROLEUM CO. 10/03/1973 BK108 PG 437 WY LINCOLN PAGE 30 T022N R112W SEC-0021 E2SW, SE, SENW, S2NE 50065-00 USA W-0127851 10/01/1961 BK PG WY SUBLETTE T030N R113W SEC-0013 SWNE, SE 50066-00 USA W-02274 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NENW, S2NW T030N R113W SEC-0024 SE, NESW, E2NE, NWNE, E2NW 50067-00 USA W-02274-A 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NWNW 50068-00 USA EV-024526-G 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENW 50069-00 USA W 16769 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 LOTS 1,2,3,4 50070-00 USA W-05504 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0014 E2NE, NESE 50071-00 USA EV-024538-A 12/01/1948 BK PG WY SUBLETTE T030N R113W SEC-0013 SW4 50075-00 USA EV-024354 11/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0034 ALL T029N R112W SEC-0033 E2NE, SE 50076-00 ANDERSON L MCGINNIS 06/01/1953 BK 86 PG 492 WY SUBLETTE T028N R112W SEC-0019 LOT 2, SENW 50077-00 WILLIAM J MCGINNIS 03/12/1963 BK 36 PG 119 WY SUBLETTE T028N R112W SEC-0017 S2N2, N2SW, NWSE, SWSW T028N R112W SEC-0018 SE, SESW, LOT 4 T028N R112W SEC-0019 NWNE 50078-00 USA EV-024355 09/01/1949 BK PG WY SUBLETTE T029N R112W SEC-0032 E2, E2W2 T029N R112W SEC-0033 W2, W2NE 50082-00 USA EV-024470 01/01/1950 BK PG WY SUBLETTE PAGE 31 T029N R112W SEC-0027 ALL T029N R112W SEC-0028 SWSE, S2SESE, E2SESW, W2SESW, N2SESE, NW, NE, N2S2, SWSW T029N R112W SEC-0029 W2SW, NE, NW, SE, E2SW 50084-00 USA W-53496 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0029 W2E2, SW, E2NW, SWNW, NWNW T028N R112W SEC-0030 SE, LOT 2 (33.12 ACS), LOT 3 (32.59 ACS), LOT 4 (32.24 ACS), NE, E2W2 T028N R112W SEC-0031 NE, LOT 1 (31.93 ACS), LOT 2 (31.68 ACS), LOT 3 (31.42 ACS), SE, E2W2 T028N R112W SEC-0032 W2NW 50085-00 USA W-53498 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 W2NE, NWSE, E2NW, E2NESW, SWSE, S2SW, W2NESW 50087-00 USA W 92216 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0005 LOTS 1-12 S2 T028N R112W SEC-0006 LOTS 1, 3-18, E2SW, SE T028N R112W SEC-0007 LOTS 1-4, E2, E2W2 50089-00 USA W 92219 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 N2NWSW, W2 LOT 4(19.19), LOT 5(40.0), LOT 12(40.0) E2 LOT 4, S2NWSW 50093-00 USA EV-022234 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0020 LOT 5 T028N R113W SEC-0029 NE/4; E/2 NW/4; NE/4 SW/4; N/2 SE/4; SE/4 SE/4 50097-00 USA EV-023584 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0023 LOT 4 (27.24), W2NW 50099-00 USA EV-024353 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 LOTS 6,7,8, E2SW, SWSE, TRACT 43-B 50103-00 USA W-0256492 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0021 LOT 7, TRACTS 43-A, 43-C T028N R113W SEC-0028 LOTS 2,3,4,9,10, TRACTS 50-B, 50-D, LOT 11 50107-00 USA W-0637 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0015 SE, SWNE, W2 PAGE 32 50111-00 USA EV-022239 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0008 E2, E2W2 50112-00 RUTH A CHAMBERLAIN, ET VIR 01/17/1950 BK 2 PG 295 WY SUBLETTE T028N R113W SEC-0020 E2NE T028N R113W SEC-0021 W2NW 50118-00 WILLIAM J MCGINNIS, ET AL 07/30/1947 BK 2 PG 158 WY SUBLETTE T028N R113W SEC-0021 TRACT 42 50124-00 USA EV-022241 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0022 W2SW, SESW, N2, LOT 1, NESW, NWSE T028N R113W SEC-0027 S2SW 50125-00 MARY H MCGINNIS 07/01/1946 BK 2 PG 101 WY SUBLETTE T028N R113W SEC-0027 RESURVEY TRACT 48 50128-00 USA W-48908 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0017 LOTS 1,3,4,5,6, SWNE, NWSE T028N R113W SEC-0021 LOTS 1,2,3,4,5,6,8, S2NE, N2SE, SESE, TR 43-D T028N R113W SEC-0028 LOTS 1,5,6,7,8, TRS 50-A & 50-C, S2SE T028N R113W SEC-0031 LOTS 7,8 T028N R113W SEC-0032 TR 53 50130-00 USA EV-07538 01/01/1940 BK 89 PG 76 WY SUBLETTE T028N R113W SEC-0033 NWNW 50132-00 USA W-031454 03/01/1955 BK PG WY LINCOLN T026N R113W SEC-0009 E/2 50146-00 USA W-0256491 01/01/1940 BK PG WY SUBLETTE T028N R113W SEC-0033 NENW 50191-00 USA EV-024966-A 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 NWNW 50196-00 USA W-0125390 06/01/1955 BK PG WY SUBLETTE T029N R112W SEC-0030 LOTS 1, 2, 3, 4, E2W2, NWNE, S2NE, SE T029N R112W SEC-0031 E2W2, E2, LOTS 1, 2, 3, 4 PAGE 33 50197-00 USA W-0125391 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOTS 5 (39.18 AC), 6 (38.97) 50199-00 USA W-0189 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 N2NE4 50200-00 USA W-014052 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 LOTS 7(40.43 ACS), 8(39.46) 50201-00 USA EV-026216 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2SW 50202-00 USA W-10680 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 7 50205-00 ST WY 0-10799 03/02/1951 BK PG WY SUBLETTE T029N R113W SEC-0001 NENE T030N R113W SEC-0036 ALL 50206-00 USA W 21125 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 W2 T030N R113W SEC-0015 SWSW T030N R113W SEC-0021 N2 50207-00 USA W21123 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 W2NW 50208-00 USA W-04628 02/01/1956 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, S2SE, W2NE, NWSE 50210-00 ST WY 0-13662 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 E2SW, SE 50211-00 ST WY 0-11311 07/02/1951 BK PG WY SUBLETTE T030N R113W SEC-0016 S2NE 50212-00 ST WY 0-13663 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 NW, W2SW 50220-00 USA W-04015-B 02/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2NENW, W2NENW PAGE 34 50223-00 USA EV-024526 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENWNE, NWNWNE, S2NWNE 50224-00 USA EV-026171 08/01/1950 BK PG WY SUBLETTE T030N R112W SEC-0018 SESW, LOTS 1,2,3,4, NWNE, S2NE, E2NW, NESW, SE T030N R112W SEC-0032 N2SW 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 NESW, SESW 50227-00 USA W-04101-B 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2SENW, W2SENW 50228-00 USA W-056555 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0008 NWNE, S2N2, LESS 6.37 AC INCL IN 67TH RESERVOIR T030N R112W SEC-0009 SW, W2SE, SESE T030N R112W SEC-0017 S2, S2N2 T030N R112W SEC-0020 W2W2, NENW T030N R112W SEC-0033 S2N2 50229-00 USA W-27641 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2, SENW 50230-00 USA W-055073 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0027 W2 T030N R112W SEC-0029 W2W2 T030N R112W SEC-0032 N2 T030N R112W SEC-0033 N2N2 T030N R112W SEC-0034 W2NW 50232-00 USA W-36567 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 N2NE, SWNE, NWSE 50233-00 USA W-027642 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENE, SENE 50235-00 ST WY 0-20914 08/16/1956 BK 16 PG 88 WY SUBLETTE T029N R112W SEC-0016 S2SW, NWSW, SWNW: LIMITED FROM SURFACE TO BASE OF MESAVERDE FORMATION (4,500'), SE, SWNE PAGE 35 N2NE, SENE 50238-00 USA EV-024445-E 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 NE4NW4 50239-00 USA W-036663-A 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SESE 50240-00 USA EV-024445 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2SW4 50241-00 USA W-036663 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SENE, NESE 50250-00 USA W-43911 08/01/1956 BK PG WY SUBLETTE T029N R112W SEC-0013 SE, S2SW T029N R112W SEC-0024 W2NW, SW T029N R112W SEC-0025 N2NW 50253-00 USA W-53499 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0022 SWNW, S2, S2NE T029N R112W SEC-0023 NE, NWSE, E2SE, NW, N2SW T029N R112W SEC-0026 NENE 50261-01 FIRST NAT'L BNK OF KEMMERER 12/29/72 BK 48 PG 628 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9, 11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2, 5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50261-02 DANIEL E CHAPEL 03/07/1981 BK 61 PG 461 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9,11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2,5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50265-00 USA W-48517 01/01/1975 BK 68 PG 367 WY SUBLETTE T029N R112W SEC-0017 SENW, E2SW, SWSE 50330-00 ST WY #67-4099 04/02/1967 BK 42 PG 205 WY SUBLETTE T027N R112W SEC-0016 E2 BEING W2NE, SESE, LOTS 1-5, 7, PORTION LOT 6 IN SWSE (5.31 AC)-PORTION IN CONFINES GREEN RIVER BED PAGE 36 50332-00 USA W-05690 07/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0015 SWNW 50333-00 USA W-020778 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0035 E2, NW4 50335-00 USA W-05691 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0005 LOTS 5,6 50336-00 USA EV-021954 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0022 NWNE 50337-00 USA W-51101 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0003 S2S2 T027N R114W SEC-0004 S2 T027N R114W SEC-0005 LOTS 13,14,15,16, E2 LOT 23,24, W2 LOT 23 T027N R114W SEC-0009 NE, E2NW, N2SE, SESE T027N R114W SEC-0010 SWSW 50345-00 USA W-64986 09/13/1978 BK 74 PG 522 WY SUBLETTE T027N R112W SEC-0011 S2 T027N R112W SEC-0014 N/2 50356-00 USA W-0231770 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 NW4NW4 50357-00 USA W-0231771 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 W2SW4 50358-00 USA W-0231772 06/01/1952 BK 69 PG 549 WY SUBLETTE T028N R113W SEC-0002 SWNW, NWSW T028N R113W SEC-0003 NWSE, S2NE, NESE, LOTS 5 & 6 50359-00 USA W-024931-A 10/01/1948 BK PG WY SUBLETTE T029N R113W SEC-0025 SENW, SWNW 50360-00 USA EV-025930 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0023 E2W2 50361-00 USA W-031992 02/01/1950 BK 31 PG 206 WY SUBLETTE PAGE 37 T029N R113W SEC-0026 N2NE4, NE4NW4 50363-00 USA W-014051 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 8 50364-00 USA W-02683 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 E2SW, SWSE 50366-00 USA EV-021767 09/01/1950 BK 89 PG 10 WY SUBLETTE T029N R113W SEC-0035 SE4 50374-00 USA W-62801 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0007 LOTS 1 THRU 4, E2, E2W2 T031N R113W SEC-0018 LOTS 1 THRU 4, E2, E2W2 50380-00 USA W-60577 11/01/1977 BK 88 PG 764 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1,2,3,4, E2, E2W2 T028N R111W SEC-0031 NE, E2SE T028N R111W SEC-0032 W2 50422-00 USA W-11603 04/01/1968 BK PG WY SUBLETTE T028N R114W SEC-0021 NE, SE 50424-00 ST WY 66-5165 03/02/1966 BK PG WY SUBLETTE T028N R114W SEC-0016 NENE, NW, N2SW, SE, SENE, S2SW, W2NE 50425-00 USA W-2120 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0015 NW, SW T028N R114W SEC-0022 SW 50427-00 USA W-055275 02/01/1959 BK PG WY SUBLETTE T026N R112W SEC-0022 NW, N2SW, S2SW 50428-00 BETTE M THOMPSON 07/06/1976 BK 53 PG 154 WY SUBLETTE T029N R113W SEC-0004 W2SW, SESW T029N R113W SEC-0005 E2SE T029N R113W SEC-0007 NESE, E2NE PAGE 38 T029N R113W SEC-0008 N2NE, W2NW, NWSW, NESW, SE SENE, SENW, S2SW T029N R113W SEC-0009 N2NW, S2NW, W2SW T029N R113W SEC-0017 E2NW, NWNE 50439-00 USA W-73977 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0017 NWNW, E2, E2NW, NESW T032N R114W SEC-0020 NE, N2SE 50507-00 USA W-67176 08/01/1979 BK223 PG 400 WY LINCOLN T026N R111W SEC-0006 SENW, SWNE, W2SE, LOTS 3,4,5,6,7 T026N R111W SEC-0007 W2E2 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW TO29N R113W SEC-0003 NESE 57132-00 MONTE NORRIS 03/12/1985 BK 74 PG 285 WY SUBLETTE T031N R113W SEC-0019 E2SW, S2SE, LOTS 2, 4 T031N R113W SEC-0030 NENW, N2NE T031N R114W SEC-0023 SENE T031N R114W SEC-0024 NW, N2SE, SESE, S2NE 58005-00 USA WYW-116385 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0019 LOTS 1,3, N/2NE, E/2NW T031N R113W SEC-0030 LOTS 1,2,3,4, E/2SW 58343-00 USA W-34033 05/01/1972 BK 57 PG 280 WY SUBLETTE T027N R111W SEC-0029 NENE 58344-00 USA W-35398 07/01/1972 BK 63 PG 605 WY SUBLETTE T027N R111W SEC-0008 SWSE T027N R111W SEC-0017 NE 58345-00 USA W-35399 07/01/1972 BK 64 PG 633 WY SUBLETTE T027N R111W SEC-0015 N2 58346-00 USA W-36422 10/01/1972 BK 57 PG 359 WY SUBLETTE T027N R111W SEC-0022 N2 PAGE 39 T027N R111W SEC-0023 ALL T027N R111W SEC-0025 SE, W2 T027N R111W SEC-0026 ALL 58347-00 USA W-51347 08/01/1975 BK 61 PG 447 WY SUBLETTE T027N R111W SEC-0005 NW,SW T027N R111W SEC-0006 SE, S2NE T027N R111W SEC-0007 NE T027N R111W SEC-0008 NW, N2SW 58348-00 USA W-54136 04/01/1976 BK 64 PG 638 WY SUBLETTE T027N R111W SEC-0014 ALL T027N R111W SEC-0015 S2 58349-00 USA W-54137 04/01/1976 BK 64 PG 155 WY SUBLETTE T027N R111W SEC-0017 SE T027N R111W SEC-0020 NE 58350-00 USA W-58724 05/01/1977 BK 54 PG 470 WY SUBLETTE T027N R111W SEC-0019 LOTS 1-4, E2W2, W2SE, SWNE T027N R111W SEC-0030 LOTS 1-3, E2W2, E2 58351-00 USA W-59776 09/01/1977 BK 64 PG 278 WY SUBLETTE T027N R111W SEC-0020 NESW 58352-00 USA W-62117 02/01/1978 BK 60 PG 198 WY SUBLETTE T027N R111W SEC-0028 NW, N2SW, SESW 58353-00 USA W-62508 11/01/1978 BK 57 PG 187 WY SUBLETTE T027N R111W SEC-0029 SE, SENE, W2, W2NE 58354-00 USA W-62875 04/01/1978 BK 68 PG 533 WY SUBLETTE T027N R111W SEC-0030 LOT 4 58355-00 USA W-63490 06/01/1978 BK 66 PG 168 WY SUBLETTE T027N R111W SEC-0032 NW, N2SW, LOT 2 58356-00 USA W-63821 07/01/1978 BK 57 PG 195 WY SUBLETTE T027N R111W SEC-0032 LOTS 3 AND 4, N2SE, NE PAGE 40 58357-00 USA W-67808 06/01/1979 BK PG WY SUBLETTE T027N R111W SEC-0006 N2NE T027N R111W SEC-0007 SE T027N R111W SEC-0018 E2NE, E2SE T027N R111W SEC-0019 E2NE, E2SE 58358-00 USA W-68116 07/01/1979 BK708 PG1493 WY SWEETWATER T026N R111W SEC-0004 SW, LOTS 1-4, S2N2, SE T026N R111W SEC-0010 S2N2 58359-00 USA W-68117 07/01/1979 BK 59 PG 7 WY SUBLETTE T027N R111W SEC-0008 S2SW T027N R111W SEC-0017 W2 T027N R111W SEC-0020 NW, NWSW, SE, S2SW 58360-00 USA W-68454 09/01/1979 BK 71 PG 306 WY SUBLETTE T027N R111W SEC-0028 SWSW 58960-00 USA WYW-034924 04/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0023 SWNE 58961-00 USA WYW-034927 05/01/1948 BK PG WY SUBLETTE T027N R114W SEC-0001 W2SW 58962-00 USA WYW-034930 10/01/1950 BK 86 PG 232 WY SUBLETTE T027N R114W SEC-0022 NENE T027N R114W SEC-0023 NW, NWNE 58963-00 STATE OF WYOMING #0-20476 01/16/1956 BK150 PG 285 WY SUBLETTE T028N R114W SEC-0036 N2, N2S2, S2SW 59023-00 USA EV-026053 10/01/1949 BK 86 PG 283 WY SUBLETTE T029N R113W SEC-0035 NE 59041-00 STATE OF WYOMING #0-11193 05/16/1951 BK 3 PG 350 WY SUBLETTE T029N R113W SEC-0036 ALL 75114-00 USA WY-0311662 10/01/1964 BK 38 PG 373 WY SUBLETTE T028N R114W SEC-0005 LOTS 9, 10, 14, 15, 16, 17, 18, 19 T028N R114W SEC-0008 LOTS 2, 3, 4, 5, 6, 7, 8, 9, 10 PAGE 41 11,12,13,14,15,16,17,18,19,20 T028N R114W SEC-0021 SESW, W2SW 75116-00 USA WY-51104 04/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0017 LOT 4 T208N R115W SEC-0012 NW 75117-00 USA WY-42791 01/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0005 LOTS, 7, 8, 12 T028N R114W SEC-0021 NESW, N2NW, SENW 75118-00 USA WY-51103 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0017 LOTS 1,2,3,5,6,7,8,9,10,11, 12,13,14,15,16,17,18,19,AND 20 75119-00 USA WY-320213 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0020 LOTS, 1,2,3,4,5,6,7,8,9 10 11,12,13,14,15,16,17,18,19,AND 20 75120-00 USA WY-52811 12/01/1975 BK PG WY SUBLETTE T028N R114W SEC-0022 NW 75123-00 USA WY-38076 02/01/1973 BK PG WY SUBLETTE T028N R114W SEC-0009 W2SE, E2SE, N2SW T028N R114W SEC-0010 SW 75124-00 USA WY-9578 12/01/1967 BK PG WY SUBLETTE T208N R114W SEC-0003 LOTS 7 THRU 10 LOTS 15 THRU 18 T028N R114W SEC-0004 LOTS 5 THRU 20 T028N R114W SEC-0005 NWSE, S2NE, LOTS 5, 6, 13, 20 T028N R114W SEC-0009 N2 T028N R114W SEC-0010 NW PAGE 42 50006-00 USA W-125389 09/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0019 LOTS 3(12.53) 4(12.13). E/2SW SWSE LOT 2(12.63). NENE,S2NE, N2SE, SESE, SENW 50007-00 USA W-0231774 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 S2NE, N2SE, S2SE 50009-00 USA W-0231773 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 S2NW, N2SW, S2SW 50010-00 USA EV-022755 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0011 W2 50014-00 USA W-10674 12/31/1938 BK 88 PG 775 WY SUBLETTE T029N R113W SEC-0014 SENE, E2SE T029N R113W SEC-0015 S2N2, S2 50016-00 USA W-085597 (ROW) 01/01/1958 BK PG WY SUBLETTE T027N R113W SEC-0018 SENW (ROW) 50017-00 USA EV-024756-A 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0024 LOT 2 50024-00 USA W-20039 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0033 SWNE 50026-00 USA W-054585 07/01/1951 BK PG WY SUBLETTE T027N R113W SEC-0012 NENW, SWSW 50043-00 USA W-71775 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0027 NESW, SE, SESW, S2NE, W2SW 50044-00 USA W-71776 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0028 NESW, NW, SE, SESW 50045-00 USA W-92975 11/011948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 W2 T023N R112W SEC-0028 W2SW 50055-00 USA EV-025548 01/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0026 ALL T027N R112W SEC-0027 E2 Page 43 50056-00 USA W-05923 06/01/1951 BK PG WY SUBLETTE T022N R112W SEC-0009 S2 50057-00 USA W-45370 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0020 E2SW, SE, SENW, S2NE T022N R112W SEC-0021 NWSW, SWNW 50058-00 USA W-45371 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0028 NWNW 50060-00 USA W-0319563 10/01/1965 BK PG WY LINCOLN T022N R112W SEC-0034 NW 50061-00 USA W-05924 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0015 N2S2, SWSW T022N R112W SEC-0022 N2, S2, T022N R112W SEC-0026 NE 50062-00 USA W-05925 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0026 N2SE, SWSE, W2 T022N R112W SEC-0028 E2, E2W2, SWNW, W2SW 50063-00 USA W-71772 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0010 SE, E2SW, NWSW, SWSW T022N R112W SEC-0020 W2W2, NENW, N2NE T022N R112W SEC-0021 N2N2 50064-00 USA W-71773 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0029 NWNW 50072-00 USA EV-024528 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0028 SENE, W2NE, W2, SE T028N R112W SEC-0029 E2E2 50073-00 USA W-035077 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 E2E2 50074-00 USA EV-024469 12/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0017 N2NE, E2SE, SWSE T028N R112W SEC-0020 E2NE, W2NE, SE Page 44 T028N R112W SEC-0021 ALL 50079-00 USA EV-024735 01/01/1949 BK PG WY SUBLETTE T028N R112W SEC-0006 W2 LOT 2 E2 LOT 2 50080-00 USA EV-026175 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 LOTS 1,2,3,6,7,8,9,10,11,SE,E2SW,SWSW 50081-00 USA EV-023340 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0008 NW, W2SW 50086-00 USA W-53497 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0008 E2, E2SW T028N R112W SEC-0009 N2, S2 50092-00 USA EV-020363 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0032 LOTS 2,5 50095-00 USA EV-022281 07/01/1948 BK 32 PG 690 WY SUBLETTE T028N R113W SEC-0027 LOTS 1,4,5,7,8 50096-00 USA EV-022285 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0009 ALL 50098-00 USA EV-023969 07/01/1948 BK 32 PG 37 WY SUBLETTE T028N R113W SEC-0008 W2W2 T028N R113W SEC-0027 LOTS 2,3, T028N R113W SEC-0029 W2NW 50100-00 USA EV-025535 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0010 W2 50104-00 USA EV-025992 03/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0027 SWNW 50105-00 USA WY 0516 05/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0033 E2 50106-00 USA W-0636 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0005 SW, SWNW 50108-00 USA CH-082277 06/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0028 S2NE4, SE4 50109-00 ST WY 0-7395 09/16/1948 BK PG WY SUBLETTE T029N R113W SEC-0016 E2, NW, SW Page 45 50110-00 WILLIAM J. MCGINNIS ET AL 07/30/1947 BK 2 PG 162 WY SUBLETTE T028N R113W SEC-0017 TRACT 38 (AKA NESW) TRACT 40 (AKA SWSE) 50114-00 ST WY #0-04732 09/16/1944 BK 36 PG 155 WY SUBLETTE T028N R113W SEC-0016 ALL (RESURVEY TRACT 37) 50115-00 USA W-04732 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0004 LOTS 7,8, S2NW, SW 50116-00 USA W-026038-A 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0021 E2 T029N R113W SEC-0027 NWNW T029N R113W SEC-0028 N2NE 50117-00 USA W-0195876 02/01/1962 BK PG WY SUBLETTE T029N R114W SEC-0025 E2NE 50119-00 USA W-04731 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0005 LOTS 5,6,7,8, S2NE, SE, SENW 50120-00 ANDERSON L. MCGINNIS ET UX 07/30/1947 BK 2 PG 156 WY SUBLETTE T028N R113W SEC-0027 PT OF TRACT 49 (W2NW, SENW) T028N R113W SEC-0028 PT OF TRACT 49 (NENE) 50121-00 MARY J. HADDENHAM 07/30/1947 BK PG WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW, (RESURVEYED AND DESCRIBED AS TRACT 39) 50122-00 MARY J. (B) HADDENHAM 07/30/1947 BK 2 PG 153 WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW (RESURVEYED AND DESCRIBED AS TRACT 39) 50123-00 USA EV-025771 01/01/1948 BK 32 PG 55 WY SUBLETTE T028N R113W SEC-0022 LOT 2 T028N R113W SEC-0026 LOT 2, SWNW, W2SW 50126-00 USA W-48905 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0016 LOTS 1 THRU 7 T028N R113W SEC-0017 NWNE T028N R113W SEC-0020 LOTS 2,3,4, S2NW T028N R113W SEC-0029 SWSE, SESW Page 46 50127-00 USA W-48906 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 NWSW 50129-00 USA W-70864 10/17/1980 BK PG WY SUBLETTE T028N R113W SEC-0028 SENE-50 FT R-O-W 50148-00 USA EV-09561-B 04/23/1935 BK PG WY SUBLETTE T027N R113W SEC-0017 W2NW 50189-00 USA W-0136175 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0026 SW T030N R113W SEC-0027 E2NE, W2NE 50190-00 USA W-0136177 04/01/1951 BK 47 PG 103 WY SUBLETTE T030N R113W SEC-0022 SE 50192-00 USA W-27645 04/01/1951 BK 47 PG 103 wy SUBLETTE T030N R113W SEC-0010 W2SE, SW, NWNW, E2SE, NE, NENW, S2NW T030N R113W SEC-0014 S2SW, SWSE, N2SW, NWSE, SESE, W2NE, NW T030N R113W SEC-0022 NE, E2NW 50193-00 USA W-27644 08/01/1950 BK PG WY SUBLETTE T030N R1113W SEC-0011 NE, SE T030N R1113W SEC-0024 W2NW, NWSW, S2SW 50194-00 USA EV-024966 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 E2NE, E2NW, E2SE, SW, SWNW, W2NE, W2SE 50203-00 USA W-0231769 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2NW4 50204-00 USA EVANSTON 024241 05/01/1948 BK 18 PG 92 WY SUBLETTE T028N R113W SEC-0001 LOTS, 5,6, 9, 10, 11, SWNE, W2SE T028N R113W SEC-0012 LOTS 1-4, W2E2, W2 T028N R113W SEC-0013 LOTS 1-3, W2E2, NW 50208-00 USA W-04628 02/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, NWSE, S2SE, W2NE Page 47 50209-00 USA W-27643 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 SENW, E2SW 50217-00 USA W-16770 12/10/1948 BJ PG WY SUBLETTE T029N R112W SEC-0006 LOT 5, SENW, S2NE, NWSE T030N R112W SEC-0030 SWNE, LOTS 1-4, SE T030N R112W SEC-0031 LOTS 3, 4, E2SW, N2SE, SESW, SESE LOTS 1, 2, E2NW, NE 50219-00 USA W-053447 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0023 S2SW, SWSE 50225-00 USA W-039908 08/01/1956 BK PG WY SUBLETTE T029N R112 SEC-0024 E/2NW, E/2 T029N R112 SEC-0025 S/2, S/2N/2, N/2SE T029N R112 SEC-0035 ALL 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0020 E2NE T030N R112W SEC-0029 NESW, SESW 50259-00 YOSE CATTLE COMPANY 12/17/1981 BK 64 PG 76 WY SUBLETTE T027N R112W SEC-0003 LOTS 2(34.31 ACS); 3(39.72 ACS); 4(39.71 ACS) 5(45.51 ACS); EXCEPTING FRACTIONAL PARTS OF LOTS 3, 4, & 5, MORE FULLY DESCRIBED IN LEASE T028N R112W SEC-0026 S/2 SW T028N R112W SEC-0034 W/2,W/2; NENW; E/2 SW; W/2 SE; SENE; NESE LOT 1 (23.57 ACS) T028N R112W SEC-0035 LOT 4(41.92 ACS); W/2 NW; NWSE LOT8 (35.13 ACS) 50263-00 USA W-077883 07/01/1976 BK PG WY SUBLETTE T028N R111W SEC-0019 LOTS 2,3,4,E2,E2NENW, SWNENW,E2SW T028N R111W SEC-0020 E2 T028N R111W SEC-0029 SE, NE T028N R111W SEC-0032 NE, SE 50266-00 USA W-87038 09/01/1984 BK PG WY SUBLETTE T029N R112W SEC-0011 SWSW Page 48 50289-01 A L MAHAFFEY 12/26/1956 BK20PR PG 282 WY LINCOLN T026N R112W SEC-0006 PART OF SEC 6 & 7 T026N R112W SEC-007 PART OF SEC 6 & 7 50289-02 BABE PROBASCO ET UX 12/27/1956 BK 21 PG 31 WY LINCOLN T026N R112W SEC-0006 BEGIN 148' N SWSE S6 THEN E 610',THEN S 148' THE E ON SEC LINE BTWN S6&7 FOR 433';THEN N 835';THEN W 1043.5';THEN S 687'TO POINT OF BEGINNING 50131-01 HOWARD A. MAHAFFEY 12/26/1956 BK 20 PG 278 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION 50314-00 GUY DECKER ET UX 03/17/1957 BK 32 PG 377 WY LINCOLN T026N R112W SEC-0006 LOT 11 OF LOT 8,LOT 1 OF BLOCK 1 OF SECOND ADDITION TO TOWN OF LABARGE 50137-00 LINCOLN COUNTY #1 05/08/1957 BK 22PR PG 166 WY LINCOLN T000N R000W SEC-0000 LARGE TOWNLOTS;ORIG TOWNSITE;TULSA-BK9 LOTS 4-7;1ST ADD;TULSA-BK 12, LOTS 13-15 RIVERVIEW ADD-TULSA - BK A,LT15,-BK B, L1-4,-BK C, L13, 20, 35 - BK E, L15, 16, 19,& 20 50326-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 172 WY LINCOLN T000N R000W SEC-0000 STREETS & ALLEYS IN LABARGE,WY ORIG PLATTED TULSA, WY SHOWN ON LINCOLN M/B MAP #1&2 SEE LST FOR LST OF STREETS & ALLEYS 50328-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 176 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0007 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0018 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0019 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0020 SEE LEASE FORE METES AND BOUNDS DESCRIPTION 50334-00 USA W-8140 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0002 LOTS 1,2,3,4, S2N2, S2 (ALL) T027N R114W SEC-0003 LOTS 1,2,3,4, S2N2, N2S2 T027N R114W SEC-0004 LOTS 1,2,3,4, S2N2 T028N R114W SEC-0034 S2NE, SENW, S2 T028N R114W SEC-0035 SW Page 49 50338-00 USA W-72405 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0009 W2NW 50339-00 USA W-92223 07/01/1951 BK 65 PG 466 WY SUBLETTE T027N T114W SEC-0010 S2NE, NW, E2SW, NWSW, SW, N2NE T027N R114W SEC-0011 W2SW, N2, SE, E2SW T027N R114W SEC-0012 W2NW, NWNSW T027N R114W SEC-0014 SWNE, NW, S2, N2NE, SENE T027N R114W SEC-0015 NE, E2NW, NWNW 50340-00 USA W092222 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0015 NESW, SE 50341-00 USA W-96755 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0027 SE4 50342-00 USA W-96756 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 SE T028N R114W SEC-0034 N2N2, SWNW 50382-00 USA W-42781 01/01/1974 BK PG WY SUBLETTE T027N R111W SEC-0004 N2 T027N R111W SEC-0005 E2 T027N R111W SEC-0008 NE, N2SE. SESE T027N R111W SEC-0009 E2, W2 50421-00 USA W-20038 03/01/1969 BK PG WY SUBLETTE T027N R1114W SEC-0028 E/2NE4, NW/NE, NW/SE 50423-00 USA W-054586 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0015 NE, E2SE T028N R114W SEC-0022 E2NE, SE T028N R114W SEC-0027 W2NE, SENE 50426-00 USA W-2121 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0028 SWNE 50433-000 THEODORE JORDAN, ET AL 08/19/1954 BK 10 PG 170 WY SUBLETTE T029N R113W SEC-0004 S2SE4 Page 50 T029N R113W SEC-0009 NE T029N R113W SEC-0010 N2NW, SENW 50437-00 USA W-19959 08/01/1969 BK 2 PG WY SUBLETTE T032N R114W SEC-0008 S2NW, N2SW LOTS 3, 4, S2SW 50438-00 USA W-06009 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0007 LOTS 1 (10.71) 2, (10.05) S2NE 50454-00 USA W-0320844 12/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0033 NWNW 50505-00 USA W-38503 03/01/1973 BK103 PG 402 WY LINCOLN T026N R111W SEC-0005 LOTS 1 & 2, S2NE, SE T026N R111W SEC-0008 E2 50506-00 USA W-57837 03/01/1973 BK552 PG 318 WY SWEETWATER T026N R111W SEC-0009 ALL 56833-00 USA W-85884 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0030 SENW 56931-00 USA W-107069 01/01/1988 BK 80 PG 747 WY SUBLETTE T031N R114W SEC-0013 N2, N2SW, SESW, SE T031N R114W SEC-0014 NW T031N R114W SEC-0023 NESW, S2SW T031N R114W SEC-0024 SW T031N R114W SEC-0025 W2E2, NW, SESE 57396-00 USA WYW-112556 08/01/1988 BK PG WY SUBLETTE T029N R112W SEC-0009 SESW, SWSE T029N R112W SEC-0010 S/2S/2 T029N R112W SEC-0015 ALL 57427-00 USA W-113137 10/01/1988 BK 81 PG 756 WY SUBLETTE T032N R114W SEC-0025 E/2, SENW, SW 57543-00 USA W-113659 12/01/1988 BK 89PR PG 89 WY LINCOLN T026N R113W SEC-0032 S/2NE, NW, N/2SW, SWSW, SE Page 51 T026N R113W SEC-0033 SWNW, S/2 57544-00 USA W-113654 12/01/1988 BK267PR PG 383 WY LINCOLN T025N R113W SEC-0017 ALL T025N R113W SEC-0020 ALL T025N R113W SEC-0021 ALL 57545-00 USA W-113651 12/01/1988 BK267 PG 391 WY LINCOLN T025N R113W SEC-0004 NENE T025N R113W SEC-0005 E2, N2NW T025N R113W SEC-0006 LOTS 1, 6, 10, E2 T025N R113W SEC-0007 LOTS 3, 4, 6, THRU 12, NENE, SE, S2NE T025N R113W SEC-0008 NE, N2SE, SW, SWSE, S2NW T025N R113W SEC-0009 NESW, S2SW, W2NW 57546-00 USA WYW-113644 12/01/1988 BK 82 PG 153 WY SUBLETTE T028N R112W SEC-0032 NWSW 57547-00 USA WYW-113645 12/01/1988 BK 82 PG 165 WY SUBLETTE T029N R112W SEC-0017 NENW, SWNW, W/2SW T029N R112W SEC-0020 NENW T029N R112W SEC-0026 W/2NE, SENE, W/2, SE T029N R112W SEC-0030 NENE 57548-00 USA W-113661 12/01/1988 BK 82 PG 250 WY SUBLETTE T029N R113W SEC-0001 LOT 2, SWNE T029N R113W SEC-0006 LOTS 1 THRU 4 T029N R113W SEC-0007 LOT 3, 4, E/2SW, W/2SE, SESE 57641-00 USA WYW-114579 02/01/1989 BK 82 PG 446 WY SUBLETTE T027N R112W SEC-002 THAT PORTION OF GREEN RIVER RIPARIAN TO LOT 5, BEING MORE PARTICULARLY DESCRIBED ON LEASE 57824-00 USA WY-115956 06/01/1989 BK 83 PG 364 WY SUBLETTE T028N R112W SEC-0010 S/2NE, SE T028N R112W SEC-0011 SWNW, NWSW Page 52 57825-00 USA WYW-115961 06/01/1989 BK 83 PG 373 WY SUBLETTE T030N R113W SEC-0007 E/2SE T030N R113W SEC-0008 NWSW T030N R113W SEC-0018 NENE 57826-00 USA WYW-115960 06/01/1989 BK 83 PG 379 WY SUBLETTE T028N R113W SEC-0013 LOT 4 T028N R113W SEC-0024 LOT 1 57952-01 DUANE HARWARD ET UX TRUST 04/21/1989 BK275PR PG 142 WY LINCOLN T026M R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF THE REGISTER OF DEEDS, LINCOLN COUNTY, WY. 57952-02 DIAMOND H RANCH, INC. 02/28/1989 BK275PR PG 488 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT, MORE FULLY DESCRIBED IN BOOK 21 PAGE 143 AND LESS THE EUBANK FOOTHILL ESTATES,MORE FULLY DESCRIBED AT PLAT #314 OF THE OFFICE OF THE REGISTER OF DEEDS, LINCOLN CO., WY. 57952-03 WILLIAM B SPENCER ET UX 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-04 MARY H LAMBERT ET AL 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO.,WY 57952-05 ISABEL H SPENCER TRUST 04/21/1989 BK275PR PG 148 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-06 WILLIAM B SPENCER TRUST 04/21/1989 BK275PR PG 146 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-07 JEAN S STEPHENS 04/21/1989 BK275PR PG 150 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-08 GLENISLA HUNTER ET AL 04/21/1989 BK275PR PG 152 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT, MORE FULLY Page 53 DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-09 LOIS S BRADY 04/21/1989 BK275PR PG154 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-10 EUBANK CATTLE COMPANY 05/30/1989 BK276PR PG 303 WY LINCOLN T026N R112W SEC-0019 TRACT OF LAND IN SESW, S/2SE, KNOWN AS THE EUBANK FOOTHILL ESTATE, RECORDED AT PLAT #314 IN OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 58055-05 MILLER ROBERT M JR ET UX 06/22/1989 BK 83 PG 679 WY SUBLETTE T029N R112W SEC-0004 W/2SW T029N R112W SEC-0005 E/2SE, SWSE T029N R112W SEC-0008 E/2 T029N R112W SEC-0009 W/2W/2 58188-00 USA WYW-117869 11/01/1989 BK 85 PG 426 WY SUBLETTE T027N R112W SEC-0002 BED OF GREEN RIVER RIPARIAN TO LOTS 6 - 8 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0003 BED OF GREEN RIVER RIPARIAN TO LOTS 1, 6, 7, 10, 11 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0034 BED OF GREEN RIVER RIPARIAN TO LOT 2 ***SEE LEASE FOR COMPLETE DESCRIPTION*** 58189-00 USA W-117878 11/01/1989 BK 84 PG 606 WY SUBLETTE T031N R114W SEC-0009 S/2 T031 R114W SEC-0010 N/2 T031N R114W SEC-0014 N/2SW 58190-00 USA WYW-117867 11/01/1989 BK 85 PG 419 WY SUBLETTE T028N R111W SEC-0003 SW T018N R111W SEC-0002 ALL T028N R111W SEC-0027 ALL 58193-00 STATE OF WY-8900650 10/02/1989 BK 84 PG 614 WY SUBLETTE T031N R114W SEC-0016 W/2 58419-00 STATE OF WYOMING #89-00780 12/02/1989 BK 85 PG 389 WY SUBLETTE Page 54 T030N R112W SEC-0016 ALL 58420-00 STATE OF WYOMING #89-00781 12/02/1989 BK 85 PG 39 WY SUBLETTE T030N R112W SEC-0028 S/2NE 58421-00 STATE OF WYOMING #89-00782 12/02/1989 BK 85 PG 393 WY SUBLETTE T030N R112W SEC-0032 NESE, SWSE 58423-00 USA WY-95121 11/01/1985 BK 84 PG 623 WY SUBLETTE T030N R112W SEC-0007 LOTS 2, 3, 4,, W/2NE, SENE, E/2SW, (LESS 6 ACRES) T030N R112W SEC-0027 SWSE T030N R112W SEC-0032 NWSE 58424-00 USA WYW-118696 01/01/1990 BK 85 PG 382 WY SUBLETTE T031N R114W SEC-0005 LOT 4(41.15), SWNW, NWSW, S/2S/2 T031N R114W SEC-0008 NE, S/2 T031N R114W SEC-0017 ALL T031N R114W SEC-0020 ALL 58521-00 GORDON W BRAY, ET UX 11/10/1989 BK 84 PG 653 WY SUBLETTE T030N R112W SEC-0026 W/2SW, SWNW T030N R112W SEC-0027 S/2NE, N/2SE, SESE T030N R112W SEC-0034 N/2NE, E/2NW 58551-00 USA W-106177 11/01/1987 BK PG WY SUBLETTE T030N R112W SEC-0015 NWNW T030N R112W SEC-0017 N/2NW (LESS 1.37 ACRES, MORE OR LESS IN T030N R112W SEC-0020 W/2E/2, SENW, NESW 58561-01 HELEN JENKINS O'NEIL 12/12/1989 BK 85 PG 91 WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58561-02 MIRIAM JENKINS BAILEY 12/11/1989 BK 85 PG 87 WY SUBLETTE T030N R112W SEC-0020 E/2SE Page 55 T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW,S/2 58561-03 JOHN PERRY BARLOW, ET UX 12/11/1989 BK 85 PG WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58562-00 BRUCE E JONES ET UX 11/13/1989 BK281PR PG 592 WY LINCOLN T025N R113W SEC-0006 LOTS 3(17.85),4(17.00),5(40.00),7(40.00), 11(40.00) 59157-01 PAUL HOMER, ET UX 05/22/1990 BK 86 PG 559 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-02 WILLIAM CHARLES CHRISTY 05/23/1990 BK 86 PG 571 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-03 KIMBERLY S CHRISTY, ET UX 05/22/1990 BK 86 PG 567 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-04 CATHLEEN E CHRISTY THOMAS 05/22/1990 BK 86 PG 563 WY SUBLETTE T030 R112W SEC-0032 S/2, SW/4 59162-00 USA WYW-112560 07/01/1988 BK PG WY SUBLETTE T030N R112W SEC-0013 N/2, NE/4 AND SE/4, NE/4 T030N R112W SEC-0025 ALL T030N R112W SEC-0026 N/2 AND SE/4 T030N R112W SEC-0035 W/2 59195-00 USA WYW-121426 10/01/1990 BK 86 PG 718 WY SUBLETTE T031N R114W SEC-0012 E2 75002-00 USA WY-107066 01/01/1988 BK PG WY SUBLETTE T024N R114W SEC-0004 LOT 13 T024N R114W SEC-0008 NE, SW T024N R114W SEC-0017 N2, SW T024N R114W SEC-0020 N2, N2S2, S2SW Page 56 75004-00 USA WYW-122224 11/01/1990 BK PG WY LINCOLN T025N R112W SEC-0027 NENE, LOTS 1,2,6 75025-01 ELIZABETH D BENNETT 06/01/1990 BK291PR PG 311 WY LINCOLN T025N R112W SEC-0005 LOT 9(1.50), 13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-02 DORISE E HOUSLEY 10/24/1990 BK291PR PG 455 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-03 DENESE STACY 10/24/1990 BK291PR PG 398 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-04 ALVIN MARX, ET UX 10/24/1990 BK291PR PG 638 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-05 ERWIN MARX, ET UX 10/24/1990 BK291PR PG 453 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-06 DOROTHY J MCGINNIS ET VIR 10/24/1990 BK291PR PG 396 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-07 ELDON E MARX, ET UX 10/24/1990 BK291PR PG 394 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75026-00 RUBY D JETKOSKI, ET AL 06/13/1990 BK288PR PG 92 WY LINCOLN T025N R112W SEC-0027 LOTS 4(21.68), 5(36.03), 9(25.66), 10(39.93) AND ALL RIPARIAN RIGHTS TO SAID LOTS, S2SW, W2SE T025N R112W SEC-0028 LOTS 8(37.79), 9(14.07) Page 57 75034-00 USA WYW-109319 (ROW) 12/28/1988 BK PG WY LINCOLN T026N R111W SEC-0005 SESW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG. SWSE, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG T026N R111W SEC-0008 NENW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG 75035-01 BRUCE E JONES, ET UX 06/09/1990 BK288PR PG 86 WY SUBLETTE T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF NWNW OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE,LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY BOUNDARY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W, 1747; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING IN 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET FOR AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17' SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED, WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7' T025N R112W SEC-008 THOSE PORTIONS OF LOTS 3,6, AN 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 THAT PORTION OF THE SWNW AND NWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AND THAT PORTION OF THE SWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189; AND NORTH OF THE ACCESS DIRT ROAD LOT 2(17.72), 3(29.79), 6(37.38) AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0018 SENE, NESE AND THAT PORTION OF THE SESE LYING NORTH OF THE ACCESS ROAD T025N R112W SEC-0020 LOTS 2(29.19), 5(9.29), 9(29.12), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 LOTS 1,2 7 75035-2 CECIL R JONES, ET UX 06/09/1990 BK288PR PG 89 WY LINCOLN T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF Page 58 NWN OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE, LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W. 1747'; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING N 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET OF AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17, SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED. WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7 T025N R112W SEC-0008 THOSE PORTIONS OF LOTS 3, 6, AND 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 LOTS 2(17.72), 3(29.79), 637.38, AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY # 189 ***SEE SECTION 0000 FOR ACREAGE*** T025N R112W SEC-0019 SESE, NESE AND THAT PORTION OF THE NENE LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189 AND BOUNDED ON THE N BY THAT CERTAIN LINE AS DEEDED IN BOOK 84 PHOTOSTATIC RECORDS AT PAGE 209 IN LINCOLN CO., WY T025N R112W SEC-0020 THAT PORTION OF THE W2W2 LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189, AND BOUNDED ON THE N BY THAT CERTAIN RIGHT OF WAY CENTER LINE AS DEEDED IN BOOK 884 PHOTOSTATIC RECORDS AT PG 209, LINCOLN CO., WY LOTS 2(29.19), 5(9.29), 9(29.12), 10(23.65), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 THAT PORTION OF THE NWNW LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189. LOTS 1, 2, 7 75044-00 USA WYW-82343 02/01/1983 BK PG WY SUBLETTE T030N R113W SEC-0005 N2SE, SWSE T030N R113W SEC-0007 NE Page 59 75045-00 ARDATH E HARMISON 11/08/1990 BK292 PG 594 WY LINCOLN T025N R112W SEC-0008 LOTS 4, 5, AND 8 T025N R112W SEC-0017 LOT 1 AND NWNE 75046-00 USA WYW-113668 12/01/1988 BK PG WY LINCOLN T025N R114W SEC-0001 LOTS 1-5, 8-11, 13-18, AND W/2 T025N R114W SEC-0002 N2, SE T025N R114W SEC-0003 ALL T025N R114W SEC-0034 TOWNSHIP 25 1/2M-RANGE 114W LOTS 1, 2, 3, 4 T025N R114W SEC-0035 TOWNSHIP 25 1/2N-RANGE 114W LOTS 3, 4 75111-00 USA WYW-125000 10/01/1991 BK 87 PG 720 WY SUBLETTE T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 75115-00 USA W-26615 12/01/1970 BK PG WY SUBLETTE T028N R114W SEC-0005 SWSE E - RECORD TITLE 75121-00 USA WY-43217 02/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0008 LOT 1 75122-00 USA WY-6317 07/01/1967 BK PG WY SUBLETTE T028N R114W SEC-0005 LOT 11 74127-00 USA WY-320214 11/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0034 N2, N2S2, LOTS 1-4 T029N R114W SEC-0035 N2, N2S2, LOTS 1-4 75171-00 STATE OF WYOMING 89-00105 02/02/1989 BK PG WY LINCOLN T026N R113W SEC-0022 S2SW 75173-00 USA WYW-126688 05/01/1992 BK PG WY LINCOLN T024N R114W SEC-0007 NE T025N R114W SEC-0008 NW T024N R114W SEC-0021 SW Page 60 50029-00 USA EV-26176-B 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0032 NENE 50031-00 USA W-21127 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0027 NW4, S2 T030N R113W SEC-0034 NE 50033-00 USA W-21128 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 SW 50188-00 USA W-05991 06/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0003 LOTS 1(40.50), 2(39.99), 3(39.95), 4(39.90) T030N R113W SEC-0004 LOTS 1(39.89) 2(39.90) 50271-00 USA W-044101 10/01/1950 BK PG WY LINCOLN T026N R113W SEC-0017 E2 T026N R113W SEC-0020 N2 T026N R113W SEC-0021 N2 57542-00 USA WYW-113640 12/01/1988 BK 82 PG 160 WY SUBLETTE T027N R111W SEC-0012 N/2, E/2SW, SE T027N R111W SEC-0013 N/2 T027N R111W SEC-0024 N/2, SW 57575-00 USA WYW-114336 03/01/1979 BK PG WY SUBLETTE T031N R113W SEC-0030 SE, S2NE 57607-00 MICKELSON GORDON ET UX 11/01/1988 BK 82 PG 289 WY SUBLETTE T031N R113W SEC-0019 S2NE 58006-00 USA WYW-116386 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0028 NESW T031N R113W SEC-0033 SENE 58083-00 ALSADE, LTD. 09/09/1989 BK PG WY SUBLETTE T031N R113W SEC-0029 EXISTING ACCESS ROAD LOCATED; SWSE,NWSW,SWNW EITHER SIDE OF CENTERLINE, FOR THE PURPOSE OF INGRESS AND EGRESS ONLY. 58187-00 USA W-117895 11/01/1989 BK 84 PG 597 WY SUBLETTE Page 61 T031N R113W SEC-0020 NESW, S/2SW, N/2SE, SWSE T031N R113W SEC-0021 SWNW, NESW, W/2SE T031N R113W SEC-0028 N/2NW 75048-00 USA W-107067 02/01/1988 BK PG WY SUBLETTE T025N R114W SEC-0024 LOTS 1-12, W/2 75256-00 USA EV-023768 12/01/1947 BK 31 PG 429 WY SUBLETTE T025N R113W SEC-0020 SWSW 75257-00 USA EV-022879 07/01/1947 BK 30 PG 545 WY SUBLETTE T028N R113W SEC-0019 LOTS 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17 75258-00 USA EV-023328 10/01/1948 BK 33 PG 637 WY SUBLETTE T028N R113W SEC-0030 N2NE 75259-00 USA EV-023553 06/01/1948 BK 33 PG 193 WY SUBLETTE T028N R113W SEC-0030 S2NE 75260-00 USA WY-01495 02/01/1950 BK 34 PG 83 WY SUBLETTE T028N R113W SEC-0018 LOTS 11, 12,13, 14, 15, 16, 17, 18, W2SE 75237-00 ST WY-86-00117 02/02/1986 BK236 PG 470 WY LINCOLN T026N R112W SEC-0016 NW, NWNE, S2NE, S2
EXHIBIT C TO HYDROCARBON EXCHANGE AGREEMENT OWNERS'S POINTS OF RECEIPT
TOMAHAWK BIG BLUE MATAGORDA SOUTH TEXAS TOTAL Daily Vol. Monthly Vol. Daily Vol. Monthly Vol. Daily Vol. Monthly Vol. Daily Vol. Monthly Vol. Daily Vol. Monthly Vol. (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) (MMBtu's) Oct-93 4,689 145,359 2,010 62,310 3,349 103,819 5,955 184,605 16,003 496,093 Nov-93 4,846 145,380 2,077 62,310 3,461 103,830 6,153 184,590 16,537 496,110 Dec-93 4,689 145,359 2,010 62,310 3,349 103,819 5,955 184,605 16,003 496,093 Jan-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Feb-94 14,726 412,328 6,311 176,708 10,519 294,532 18,700 523,600 50,256 1,407,168 Mar-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Apr-94 14,726 441,780 6,311 189,330 10,519 315,570 18,700 561,000 50,256 1,507,680 May-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Jun-94 14,726 441,780 6,311 189,330 10,519 315,570 18,700 561,000 50,256 1,507,680 Jul-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Aug-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Sep-94 14,726 441,780 6,311 189,330 10,519 315,570 18,700 561,000 50,256 1,507,680 Oct-94 14,726 456,506 6,311 195,641 10,519 326,089 18,700 579,700 50,256 1,557,936 Nov-94 12,804 384,120 6,653 199,590 11,088 332,640 19,711 591,330 50,256 1,507,680 Dec-94 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Jan-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Feb-95 12,804 358,512 6,653 186,284 11,088 310,464 19,711 551,908 50,256 1,407,168 Mar-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Apr-95 12,804 384,120 6,653 199,590 11,088 332,640 19,711 591,330 50,256 1,507,680 May-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Jun-95 12,804 384,120 6,653 199,590 11,088 332,640 19,711 591,330 50,256 1,507,680 Jul-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Aug-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Sep-95 12,804 384,120 6,653 199,590 11,088 332,640 19,711 591,330 50,256 1,507,680 Oct-95 12,804 396,924 6,653 206,243 11,088 343,728 19,711 611,041 50,256 1,557,936 Nov-95 11,366 340,980 6,908 207,240 11,513 345,390 20,468 614,040 50,255 1,507,650 Dec-95 11,366 352,346 6,908 214,148 11,513 356,903 20,468 634,508 50,255 1,557,905 Jan-96 19,176 594,456 11,655 361,305 19,425 602,175 0 0 50,256 1,557,936 Feb-96 19,176 556,104 11,655 337,995 19,425 563,325 0 0 50,256 1,457,424 Mar-96 19,176 594,456 11,655 361,305 19,425 602,175 0 0 50,256 1,557,936 Apr-96 19,176 575,280 11,655 349,650 19,425 582,750 0 0 50,256 1,507,680 May-96 19,176 594,456 11,655 361,305 19,425 602,175 0 0 50,256 1,557,936 Jun-96 19,176 575,280 11,655 349,650 19,425 582,750 0 0 50,256 1,507,680 Jul-96 14,324 444,044 6,814 211,234 11,613 360,003 17,505 542,655 50,256 1,557,936 Aug-96 14,324 444,044 6,814 211,234 11,613 360,003 17,505 542,655 50,256 1,557,936 Sep-96 14,324 429,720 6,814 204,420 11,613 348,390 17,505 525,150 50,256 1,507,680 Oct-96 14,324 444,044 6,814 211,234 11,613 360,003 17,505 542,655 50,256 1,557,936 Nov-96 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Dec-96 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Jan-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Feb-97 14,324 401,072 9,319 260,932 0 0 26,613 745,164 50,256 1,407,168 Mar-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Apr-97 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 May-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Jun-97 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Jul-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Aug-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Sep-97 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Oct-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Nov-97 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Dec-97 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Jan-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Feb-98 14,324 401,072 9,319 260,932 0 0 26,613 745,164 50,256 1,407,168 Mar-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Apr-98 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 May-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Jun-98 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Jul-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Aug-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Sep-98 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Oct-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Nov-98 14,324 429,720 9,319 279,570 0 0 26,613 798,390 50,256 1,507,680 Dec-98 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Jan-99 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 Feb-99 14,324 401,072 9,319 260,932 0 0 26,613 745,164 50,256 1,407,168 Mar-99 14,324 444,044 9,319 288,889 0 0 26,613 825,003 50,256 1,557,936 28,150,916 16,124,578 13,222,406 40,280,831 97,778,731
EX-10.39.B 12 FIRST AMENDMENT TO PRODUCTION AND DELIVERY EXHIBIT 10.39(b) FIRST AMENDMENT TO PRODUCTION AND DELIVERY AGREEMENT Reference for all purposes is hereby made to that certain Production and Delivery Agreement (the "Delivery Agreement "), dated September 25, 1992, by and between ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") and CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), pertaining to certain oil and gas leases, wells and related interests, which Delivery Agreement is recorded as set forth on Exhibit C hereto under the caption "Production and Delivery Agreement." WHEREAS, Grantor and Grantee desire to amend the Delivery Agreement as hereinafter set forth as of April 1, 1993 (the "Effective Date") to release certain Leases and Subject Wells from the Delivery Agreement and to add certain additional oil and gas leases and related interests and to make other changes as provided herein: NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars and no/100ths ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Delivery Agreement as follows: 1. Capitalized terms as used herein shall have the meanings given to them in the Delivery Agreement unless otherwise defined herein. 2. Exhibit A to the Delivery Agreement is hereby amended by deleting those Leases set forth on Exhibit A-1 hereto and those Subject Wells set forth on Exhibit A-2 hereto and adding those oil and gas leases and related interests set forth on Exhibit B hereto. 3. Except as expressly amended hereby, the Delivery Agreement shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Delivery Agreement as hereby amended. EXECUTED in multiple originals this 21st day of May, 1993, but effective as of the Effective Date. GRANTOR: WITNESSES: ENRON OIL & GAS COMPANY By: Name: D. Weaver Title: Agent and Attorney-in-fact GRANTEE: WITNESSES: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp. General Partner By: Name: Andrew S. Fastow Title: Vice President EXHIBIT "A-1" - Description of Deleted Leases EXHIBIT "A-2" - Description of Deleted Wells EXHIBIT "B" - Description of Added Leases EXHIBIT "C" - Recordation Schedule - Production and Delivery Agreement 2 STATE OF TEXAS COUNTY OF HARRIS On this _____ day of _____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ________________________, to me personally known, who, being by me duly sworn, did say that he is the ___________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, and that the instrument was signed in behalf of the corporation by authority of its Board of Directors and that ____________________ acknowledged the instrument to be the free act and deed of the corporation. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary STATE OF TEXAS COUNTY OF HARRIS On this _____ day of ____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ______________________, to me personally known, who, being by me duly sworn, did say that he is the ________________ of Enron Big Piney Corp., General Partner of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, and that the instrument was signed on behalf of said corporation, acting as General Partner of said limited partnership and that _____________________ acknowledged the instrument to be the free act and deed of the limited partnership. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary 3 EXHIBIT A-1 Attached to and made a part of that certain First Amendment to Production and Delivery Agreement effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED LEASES SUBLETTE COUNTY, WYOMING
ENRON LEASE LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDING 0050097-000 EV-023584 Township 28 North, Range 113 West, 6th P.M. 6/1/48 Not Recorded Section 23: Lot 4 (27.24), W/2NW/4 Below 1500' above the top of the Frontier formation 0050109-000 State WY- Township 29 North, Range 113 West, 6th P.M. 9/16/48 Not Recorded 07395 Section 16: E/2 Below 1500' above the top of the Frontier formation 0050115-000 WY-04732 Township 28 North, Range 113 West, 6th P.M. 2/1/51 Not Recorded Section 4: Lots 7 (35.76), 8 (36.27), S/2NW/4, SW/4 Below 1500' above the top of the Frontier formation 0050116-000 W-026038-A Township 29 North, Range 113 West, 6th P.M. 2/1/50 BK 31, PG 206 Section 21: E/2 Section 27: NW/4NW/4 Section 28: N/2NE/4 Below 1500' above the top of the Frontier formation 0050125-000 McGinnis, Township 28 North, Range 113 West, 6th P.M. 7/1/46 BK 2, PG 101 Mary et al Section 27: Resurvey Tract 48 From 1500' above the top of the Frontier formation to the base of the Frontier formation LINCOLN COUNTY, WYOMING 0050272-000 EV-09156-B Township 26 North, Range 113 West, 6th P.M. 6/1/48 BK 17, PG 283 Section 5: E/2SE/4 No depth limitations
Page> EXHIBIT A-2 Attached to and made a part of that certain First Amendment to Production and Delivery Agreement effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED WELLS
WELL WELL LEGAL WI NRI WI NRI NAME NUMBER DESCRIPTION BPO BPO APO APO SHU 65-05G 06152-00-00-1 Township 26 North, Range 25.000% 20.350% 25.000% 20.3500% 113 West, 6th P.M. Section 5: E/2 Lincoln County, Wyoming Tip Top Unit 06144-00-00-1 Township 27 North, Range 1.4233% 1.0870% 1.4233% 1.0870% Participating 113 West, 6th P.M. Area "B" Parts of Sections 5 and 6 Township 28 North, Range 113 West, 6th P.M. Portions of Sections 6-8, 16, 17 and 18 Township 28 North, Range 114 West, 6th P.M. Portions of Sections 1 and 12 Sublette County, Wyoming EXHIBIT B Attached to and made a part of that certain First Amendment to Production and Delivery Agreement effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee.
ADDED LEASES SUBLETTE COUNTY, WYOMING
MOBIL LEASE LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDING W-2645 E-025771 Township 28 North, Range 113 West, 1/1/48 Not Available 6th P.M. Section 22: Lot 2 (23.91) From the surface to 1500' above the top of the Frontier formation W-2579 E-023969 Township 28 North, Range 113 West, 7/1/48 Not Available 6th P.M. Section 27: Lots 2 (13.62), 3 (9.19) Section 29: W/2NW/4 From the surface to 1500' above the top of the Frontier formation W-2571 E-023768 Township 28 North, Range 113 West, 12/1/47 BK 31, PG 429 6th P.M. Section 20: SW/4SW/4 From the surface to 1500' above the top of the Frontier formation W-2569 E-022879 Township 28 North, Range 113 West, 7/1/47 Not Available 6th P.M. Section 19: Lots 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16 and 17 From the surface to 1500' above the top of the Frontier formation W-2568 E-023328 Township 28 North, Range 113 West, 10/1/48 Not Available 6th P.M. Section 30: N/2NE/4 From the surface to 1500' above the top of the Frontier formation W-2566 E-023553 Township 28 North, Range 113 West, 6/1/48 Not Available 6th P.M. Section 30: S/2NE/4 From the surface to 1500' above the top of the Frontier formation W-2586 W-01495 Township 28 North, Range 113 West, 2/1/50 Not Available 6th P.M. Section 18: Lots 11, 12, 13, 14, 15, 16, 17, 18 (W/2SE/4) From the surface to 1500' above the top of the Frontier formation EXHIBIT C Attached to and made a part of that certain First Amendment to Production and Delivery Agreement effective as of the 1st day of April, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee.
Document Filing Entity Recording Reference Production and Delivery Agreement dated Lincoln County Book 317 PR, Page 537 September 25, 1992 between EOG and Cactus File No. 755519 October 8, 1992 Sublette County Book 90 O&G, Page 1 File No. 238875 October 2, 1992
EX-10.39.C 13 SECOND AMENDMENT TO PRODUCTION AND DELIVERY EXHIBIT 10.39(c) SECOND AMENDMENT TO PRODUCTION AND DELIVERY AGREEMENT Reference for all purposes is hereby made to that certain Production and Delivery Agreement dated September 25, 1992, by and between ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") and CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), as amended by that certain First Amendment to Production and Delivery Agreement dated effective April 1, 1993 (the "Delivery Agreement"), pertaining to certain oil and gas leases, wells and related interests, which Delivery Agreement is recorded as set forth on Exhibit C hereto. WHEREAS, Grantor and Grantee desire to amend the Delivery Agreement as hereinafter set forth as of July 1, 1993 (the "Effective Date") to release certain Leases and Subject Wells from the Delivery Agreement and to add certain additional oil and gas leases, wells and related interests and to make other changes as provided herein: NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars and no/100ths ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Delivery Agreement as follows: 1. Capitalized terms as used herein shall have the meanings given to them in the Delivery Agreement unless otherwise defined herein. 2. Exhibit A to the Delivery Agreement is hereby amended by deleting those Leases set forth on Exhibit A-1 hereto and those Subject Wells set forth on Exhibit A-2 hereto and adding those oil and gas leases and related interests set forth on Exhibit B-1 hereto and those wells set forth on Exhibit B-2 hereto. 3. Except as expressly amended hereby, the Delivery Agreement shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Delivery Agreement as hereby amended. 4. This instrument is being executed in several counterparts, all of which are identical. Each of such counterparts shall for all purposes be deemed to be an original and all such counterparts shall together constitute but one and the same instrument. WITNESS THE EXECUTION HEREOF, this 29th day of September, 1993, to be effective as of the Effective Date. GRANTOR: WITNESSES: ENRON OIL & GAS COMPANY By: Name: G. E. Uthlaut Title: Sr. Vice President GRANTEE: WITNESSES: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp. General Partner By: Name: Andrew S. Fastow Title: Vice President EXHIBIT "A-1" - Description of Deleted Leases EXHIBIT "A-2" - Description of Deleted Wells EXHIBIT "B-1" - Description of Added Leases EXHIBIT "B-2" - Description of Added Wells EXHIBIT "C" - Recordation Schedule - Production and Delivery Agreement and First Amendment to Production and Delivery Agreement -2- STATE OF TEXAS COUNTY OF HARRIS On this _____ day of _____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ________________________, to me personally known, who, being by me duly sworn, did say that he is the ___________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, and that the instrument was signed in behalf of the corporation by authority of its Board of Directors and that ____________________ acknowledged the instrument to be the free act and deed of the corporation. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary STATE OF TEXAS COUNTY OF HARRIS On this _____ day of ____________________, 1993, before me, the undersigned Notary Public in and for the State of Texas, personally appeared ______________________, to me personally known, who, being by me duly sworn, did say that he is the ________________ of Enron Big Piney Corp., General Partner of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, and that the instrument was signed on behalf of said corporation, acting as General Partner of said limited partnership and that _____________________ acknowledged the instrument to be the free act and deed of the limited partnership. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary 3 EXHIBIT A-1 Attached to and made a part of that certain Second Amendment to Production and Delivery Agreement effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED LEASES SUBLETTE COUNTY, WYOMING
50427-000 W-055275 Township 26 North, Range 112 West, 6th P.M 2/1/59 Not Recorded Section 22: NE/4NE/4, SE/4, S/2NE/4 Section 23: NW/4NW/4, SW/4NW/4,3 E/2NW/4, SW/4 Limited to only the Frontier formation under said lands.
EXHIBIT A-2 Attached to and made a part of that certain Second Amendment to Production and Delivery Agreement effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. DELETED WELLS LINCOLN COUNTY, WYOMING
WELL NAME WELL NUMBER LEGAL DESCRIPTION WI BPO NRI BPO WI APO NRI APO Fontenelle 11-36 0912100001 Township 26 North, Range 112 West, 6th P.M. .0170308 .0148326 .0195606 .0161375 Section 36: NW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 12-03 0912200001 Township 25North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 3: SW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 13-11 0912300001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 11: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 13-24 0912400001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195597 .0184859 Section 24: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 13-34 0012400001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195597 .0184859 Section 34: NW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-01 0912500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 1: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-02 0912600001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 2: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 14-04 0912800001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: SW/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 14-06 0912900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 6: Lot 7 Formation: Consl. Frontier ABCD Fontenelle 14-27 0912700001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 27: SW/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 22-36 0913100001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 36: SE/4NW/4 Formation: Consl. Frontier ABCD Fontenelle 23-07F 0913400001 Township 25 North, Range 111 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 7: NE/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 23-25 0913200001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 25: NE/4SW/4 Formation: Consl. Frontier ABCD Fontenelle 23-33 0913300001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 33: Lot 7 Formation: Consl. Frontier ABCD Fontenelle 31-04 0913500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 31-05 0913600001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 4: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 31-06F 0913700001 Township 25 North, Range 111 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 6: NW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 32-10 0913800001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 10: SW/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 33-04 0914100001 Township 25 North, Range 112 West, 6th P.M. .0148326 .0148326 .0195606 .0161375 Section 4: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-12 0128800001 Township 15 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 12: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-13 0913900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 13: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 33-24 0914000001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 25: NW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-03 0914000001 Township 15 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 3: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-09 0914500001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 9: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-23 0914200001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 23: SW/4SE/4 Formation: Consl. Frontier ABCD Fontenelle 34-28 0914300001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 28: Lot 9 Formation: Consl. Frontier ABCD Fontenelle 41-09 0914900001 Township 25 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 9: NE/4NE/4 Formation: Consl. Frontier ABCD Fontenelle 41-24 0914600001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 24: Lot 1 Formation: Consl. Frontier ABCD Fontenelle 41-26 0914800001 Township 26 North, Range 112 West, 6th P.M. .0134239 .0118418 .0195606 .0161375 Section 36: Lot 1 Formation: Consl. Frontier ABCD EXHIBIT B-1 Attached to and made a part of that certain Second Amendment to Production and Delivery Agreement effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee.
ADDED LEASES LINCOLN COUNTY, WYOMING
ENRON LEASE NO. LESSOR LEGAL DESCRIPTION DATE RECORDED 75237-000 ST of WY Township 26 North, Range 112 West, 6th P.M. 2/2/86 Book 236 PR, 86-00117 Section 16: NW/4, NW/4NE/4, S/2NE/4, S1/2 Page 170
EXHIBIT B-2 Attached to and made a part of that certain Second Amendment to Hydrocarbon Exchange Agreement effective as of the 1st day of July, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee. ADDED WELLS LINCOLN COUNTY, WYOMING
WELL NAME WELL NUMBER LEGAL DESCRIPTION WI BPO NRI BPO WI APO NRI APO Spur Canyon #1 0236940001 Township 26 North, Range 112 West, 6th P.M. 100% 75% 100% 75% Section 16: NE/4NW/4 West Stead 0240000001 Township 26 North, Range 112 West, 6th P.M. 100% 75% 100% 75% Canyon #22-16 Section 16: SW/4NE/4
EXHIBIT C Attached to and made a part of that certain Second Amendment to Production and Delivery Agreement effective as of the 1st day of May, 1993 between Enron Oil & Gas Company ("EOG") as Grantor and Cactus Hydrocarbon 1992-A Limited Partnership ("Cactus") as Grantee.
Document Filing Entity Recording Reference Production and Delivery Agreement dated Lincoln County Book 317 PR, Page 537 September 25, 1992 between EOG and Cactus File No. 755519 October 8, 1992 Sublette County Book 90 O&G, Page 1 File No. 238875 October 2, 1992 Production and Delivery Agreement dated Lincoln County Book 330 PR, Page 31 effective April 1, 1993 between EOG and File No. 765867 Cactus June 4, 1993 Sublette County Book 92 O&G, Page 325 File No. 241740 May 28, 1993
EX-10.39.D 14 THIRD AMENDMENT TO PRODUCTION AND DELIVERY EXHIBIT 10.39(d) THIRD AMENDMENT TO PRODUCTION AND DELIVERY AGREEMENT Reference for all purposes is hereby made to that certain Production and Delivery Agreement (the "Original Delivery Agreement"), dated September 25, 1992, by and between ENRON OIL & GAS COMPANY, a Delaware corporation ("Grantor") and CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, whose address is 1400 Smith Street, P. O. Box 1188, Houston, Texas 77251-1188 ("Grantee"), pertaining to certain oil and gas leases, wells and related interests more particularly described therein, which Original Delivery Agreement is recorded as set forth on Attachment A hereto under the caption "Original Delivery Agreement." WHEREAS, the Original Delivery Agreement was amended by that certain First Amendment to Production and Delivery Agreement (the "First Amendment to Delivery Agreement") dated effective as of April 1, 1993 from Grantor to Grantee, recorded as set forth on Attachment A hereto under the caption "First Amendment to Delivery Agreement;" and WHEREAS, the Original Delivery Agreement was further amended by that certain Second Amendment to Production and Delivery Agreement (the "Second Amendment to Delivery Agreement") dated effective as of July 1, 1993 from Grantor to Grantee, recorded as set forth on Attachment A hereto under the caption "Second Amendment to Delivery Agreement;" and WHEREAS, subsequent to the execution, delivery and recordation of the Original Delivery Agreement, pursuant to the terms of the First Amendment to Delivery Agreement and the Second Amendment to Delivery Agreement, certain Leases and Subject Wells as set forth in Parts I and III of Exhibit A to the Original Delivery Agreement have been deleted therefrom and other Leases and Subject Wells have been substituted therefor; and WHEREAS, the Original Delivery Agreement as amended by the First Amendment to Delivery Agreement and the Second Amendment to Delivery Agreement is referred to herein as the "Delivery Agreement;" and WHEREAS, Grantor and Grantee desire to amend the Delivery Agreement as hereinafter set forth effective as of October 1, 1993 (the "Effective Date"): NOW, THEREFORE, for and in consideration of the premises and of the sum of Ten Dollars ($10.00) and other good and valuable consideration, cash in hand paid to Grantor by Grantee, Grantor and Grantee do hereby amend the Delivery Agreement as follows: 1. Capitalized terms used herein shall have the meanings given to them in the Delivery Agreement unless otherwise defined herein. 2. Section 10 of the Delivery Agreement is hereby amended by deleting same and substituting the following in lieu thereof: 10. CAPITAL EXPENDITURES. Subject to the provisions of this Section 10, Grantor agrees to make the monthly capital expenditures on Schedule 2 hereto for drilling and operating the Subject Interests (including but not limited to necessary field development activities and the recompletion or reworking of any wells on the Subject Interests), as a prudent operator (and without regard to the burden of the Production Payment), except when (a) in the three month period immediately prior to the time that such capital expenditures are scheduled to be made the average daily rate of production of Hydrocarbons from all reservoirs attributable to Grantor's net revenue interest in the Subject Interests (excluding any periods of Force Majeure) exceeds the Target Deliveries (as hereinafter defined), and (b) the ratio of Tail Reserves to the quantities remaining to be delivered under the Production Payment is at least 2 to 1. "Target Deliveries" shall mean a rate of production of Hydrocarbons equal to 75 billion Btus for each day of each year beginning in 1993. The Target Deliveries and the required ratio under clause (b) above are herein collectively referred to as the "Target Delivery and Reserve Tests." If Grantor is required to make capital expenditures for any month according to this Section 10, then the amount of such capital expenditures shall be equal to the lesser of (i) the amount set forth on Schedule 2 for such month, together with the amounts of all of the capital expenditures set forth for the preceding months that Grantor did not make because the Target Delivery and Reserve Tests were met, or (ii) the amount necessary to cause the Target Delivery and Reserve Tests to be met for the such month. 3. Schedule 2 and Parts I and III to Exhibit A to the Delivery Agreement are hereby amended by deleting same and substituting Schedule 2 and Parts I and III to Exhibit A attached hereto in lieu thereof. Schedule 2 and Parts I and III to Exhibit A attached hereto are made a part of the Delivery Agreement and supersede Schedule 2 and Parts I and III to Exhibit A attached to the Delivery Agreement. 4. The term "Conveyance" as used in the Delivery Agreement shall mean that certain Conveyance of Production Payment dated September 25, 1992 from Grantor to Grantee as amended by the First Amendment to Conveyance of Production Payment dated effective as of April 1, 1993 between Grantor and Grantee, the Second Amendment to Conveyance of Production Payment dated effective as of July 1, 1993 from Grantor to Grantee and the Third Amendment to Conveyance of Production Payment dated effective as of October 1, 1993 between Grantor and Grantee, and as the same may be further amended, modified or supplemented from time to time. 5. Except as expressly amended hereby, the Delivery Agreement shall remain in full force and effect as heretofore entered into and amended. Grantor and Grantee ratify and confirm the Delivery Agreement as hereby amended. -2- EXECUTED in multiple originals this 29th day of October, 1993, but effective as of the Effective Date. GRANTOR: ATTEST: ENRON OIL & GAS COMPANY By: By: Name: D. M. Ulak Name: Andrew N. Hoyle Title: Assistant Secretary Title: Vice President GRANTEE: ATTEST: CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP By: Enron Big Piney Corp., its General Partner By: By: Name: Elaine Overturf Name: Jere C. Overdyke, Jr. Title: Deputy Corporate Secretary Title: Vice President ATTACHMENTS, EXHIBITS AND SCHEDULES: Attachment A - Recordation Schedule - Original Delivery Agreement, First Amendment to Delivery Agreement and Second Amendment to Delivery Agreement Part I to Exhibit A - Subject Interests Part III to Exhibit A - Subject Wells Schedule 2 - Capital Expenditures -3- STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by _____________________, as _____________________ of ENRON OIL & GAS COMPANY, a Delaware corporation, on behalf of such corporation this _____ day of _____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me by ______________________, as __________________ of Enron Big Piney Corp., a Delaware corporation, as General Partner on behalf of CACTUS HYDROCARBON 1992-A LIMITED PARTNERSHIP, a Delaware limited partnership, this _____ day of ____________________, 1993. Witness my hand and official seal. NOTARY PUBLIC, IN AND FOR THE STATE OF TEXAS Printed Name of Notary: My Commission Expires: -4- ATTACHMENT A Attached to and made a part of that certain Third Amendment to Production and Delivery Agreement
DOCUMENT FILING ENTITY RECORDING REFERENCE Original Delivery Agreement County Clerk Book 317 PR, Page 537 Lincoln County File No. 755519 October 8, 1992 County Clerk Book 90 O&G, Page 1 Sublette County File No. 238875 October 2, 1992 First Amendment to Delivery County Clerk Book 330 PR, Page 31 Agreement Lincoln County File No. 765867 June 4, 1993 County Clerk Book 92 O&G, Page 325 Sublette County File No. 241740 May 28, 1993 Second Amendment to Delivery County Clerk Book 336 PR, Page 685 Agreement Lincoln County File No. 772468 October 4, 1993
EXHIBIT __________ Schedule 2 To Production and Delivery Agreement Required Annual EOG Capital Expenditures Required Month Year Capital Expenditures, MM$ October 1993 1.70110 November 1993 1.70110 December 1993 1.70110 TOTAL 1993 5.10331 January 1994 1.43366 February 1994 1.43366 March 1994 1.43366 April 1994 1.43366 May 1994 1.43366 June 1994 1.43366 July 1994 1.43366 August 1994 1.43366 September 1994 1.43366 October 1994 1.43366 November 1994 1.43366 December 1994 1.43366 TOTAL 1994 17.20390 January 1995 1.76855 February 1995 1.76855 March 1995 1.76855 April 1995 1.76855 May 1995 1.76855 June 1995 1.76855 July 1995 1.76855 August 1995 1.76855 September 1995 1.76855 October 1995 1.76855 November 1995 1.76855 December 1995 1.76855 TOTAL 1995 21.22260 January 1996 0.99124 February 1996 0.99124 March 1996 0.99124 April 1996 0.99124 May 1996 0.99124 June 1996 0.99124 July 1996 0.99124 August 1996 0.99124 September 1996 0.99124 October 1996 0.99124 November 1996 0.99124 December 1996 0.99124 TOTAL 1996 11.89490 January 1997 0.38154 February 1997 0.38154 March 1997 0.38154 April 1997 0.38154 May 1997 0.38154 June 1997 0.38154 July 1997 0.38154 August 1997 0.38154 September 1997 0.38154 October 1997 0.38154 November 1997 0.38154 December 1997 0.38154 TOTAL 1997 4.57850 January 1998 0.02844 February 1998 0.02844 March 1998 0.02844 April 1998 0.02844 May 1998 0.02844 June 1998 0.02844 July 1998 0.02844 August 1998 0.02844 September 1998 0.02844 October 1998 0.02844 November 1998 0.02844 December 1998 0.02844 TOTAL 1998 0.34130 January 1999 0.21355 February 1999 0.21355 March 1999 0.21355 TOTAL 1999 0.64065 Part I to Exhibit A (Delivery Agreement)
LEASE LEASE NUMBER LESSOR DATE RECORDING ST COUNTY 50001-00 ENGER K CHRISMAN, ET AL 04/28/1950 BK 2 PG 623 WY SUBLETTE T029N R113W SEC-0010 E2SE4 T029N R113W SEC-0011 W/2SW 50003-00 ENGER K CHRISMAN, ET AL 07/01/1954 BK 10 PG 398 WY SUBLETTE T029N R112W SEC-0018 LOTS 1, 2, E2NW T029N R113W SEC-0011 E2SW, SE T029N R113W SEC-0012 S2SE, NWSW, S2SW T029N R113W SEC-0013 SESW, SENE, SE, NWNW, NWNE, NENE, NENW T029N R113W SEC-0014 N2NE, NENW T029N R113W SEC-0024 N2NE 50005-01 CHAS. P BUDD 11/24/1942 BK 1 PG 371 WY SUBLETTE T029N R113W SEC-0010 N2NE, SWNE 50005-02 THE FRANCES MARGARET GUIO 12/15/1987 BK 81 PG 327 WY SUBLETTE JUNE 16, 1982 FAMILY TRUST T029N R113W SEC-0010 NENE, SENW, SWNE, AS TO ALL DEPTHS BELOW 2,500 FT. 50008-01 PATRICK J QUEALY, ADMIN. 08/15/1957 BK 18 PG 136 WY SUBLETTE T027N R113W SEC-0028 50008-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 140 WY SUBLETTE T027N R113W SEC-0028 SWNE, S2NW 50011-00 USA EV 021983 08/01/1944 BK 31 PG 200 WY SUBLETTE T029N R113W SEC-0014 NWNW 50013-01 SELMER G LARSON 06/11/1957 BK 17 PG 2 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50013-02 JOSEPH A MINTON ET UX 08/15/1957 BK 18 PG 144 WY SUBLETTE T027N R113W SEC-0028 NWSE, N2SW, SWSW 50018-00 WILLIAM J. MCGINNIS, ET UX 10/05/1946 BK 2 PG 109 WY SUBLETTE T026N R113W SEC-0023 N2SE (PART OF TR 45) T028N R113W SEC-0024 N2/SW (PART OF TR 45), S2NE, S2NW, (AKA TR 47) 50019-00 USA EV-021741 09/01/1946 BK 88 PG 783 WY SUBLETTE T026N R113W SEC-0004 LOTS 1(39.30), 2(38.74), 3(38.18), 4(37.62), 5(40), 6(40), 7(40), 8(40), 9(40), 10(40), 11(40), 12(40), SE, NWSW T027N R113W SEC-0028 SESW, SWSE T027N R113W SEC-0029 SENE T027N R113W SEC-0032 W2SE, N2NE, SWNE T027N R113W SEC-0033 NWNE, S2NE, SE, NW 50020-00 USA EV-021743 03/01/1947 BK 86 PG 313 WY SUBLETTE T027N R113W SEC-0033 N2SW 50022-01 MATILDA BERTAGNOLLI, ET VIR 10/26/1956 BK 16 PG 150 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50022-02 THOMAS S HARROWER, ET UX 09/06/1957 BK 18 PG 2 WY SUBLETTE T027N R114W SEC-0001 LOTS 1, 2, 3, 4, S2N2 50027-00 USA W-04226 01/01/1951 BK 89 PG 154 WY SUBLETTE T030N R113W SEC-0028 SWNW, N2SW, E2NW, S2SW 50028-00 USA 2-0136178 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113N SEC-0021 S2 50047-00 USA EV-023313-A 02/01/1948 BK314 PG 227 WY LINCOLN T026N R112W SEC-0012 W2E2, LOTS 3,4 T026N R112W SEC-0013 NW, SW 50048-00 USA EV-023313-B 02/01/1948 BK288 PG 640 WY LINCOLN T026N R112W SEC-0012 W2 T026N R112W SEC-0013 LOT 3, W2NE, LOT 4, W2SE 50049-00 ST WY 0-2265 03/02/1944 BK314 PG 49 WY LINCOLN T026N R112W SEC-0016 NENE 50050-00 USA EV-025550 01/01/1948 BK 89 PG 98 WY SUBLETTE T027N R112W SEC-0027 W2 50051-00 USA EV-022929 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0034 NENE, NENE, SE, S2NE, W2 T027N R112W SEC-0035 50052-00 USA EV-026056 12/01/1949 BK 9 PG 128 WY LINCOLN T026N R112W SEC-0011 NE, NENW, N2SW, SE, SESW, SWSW, S2NW T026N R112W SEC-0014 E2, E2NW, SW, W2NW 50053-00 USA EV-022930-A 09/01/1947 BK 8 PG 484 WY LINCOLN T026N R112W SEC-0010 SENE, SENW, SWNE, N2NE, N2NW, SWNW, SW4, N2SE, S2SE T026N R112W SEC-0015 NWNW, NENW, SENW, SWNW, SW, N2N3, S2NE, SE 50054-00 USA EV-022932 09/01/1947 BK 9 OG 66 WY SUBLETTE T026N R112W SEC-0002 NESE, NWSE, SENE, SW, SWNE, S2NW, S2SE, LOTS 1, 2, 3, 4 T026N R112W SEC-0003 S2, S2N2, LOTS 1, 2, 3, 4 T026N R112W SEC-0004 SE T026N R112W SEC-0009 N2, N2SE, SESE, SW, SWSE T026N R112W SEC-0011 NWNW 50088-00 USA W-92217 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0017 N2NW, SESW T028N R112W SEC-0018 NE, LOTS 1, 2, 3, E2NW, NESW T028N R112W SEC-0019 SWNE, E2SW, W2SE, E2NE, E2SE T028N R112W SEC-0020 W2SW. MW. E2SW 50094-00 USA EV-022261 09/01/1946 BK 90 PG 107 WY SUBLETTE T026N R113W SEC-0019 SE, SWNE, SENE, LOT 5, NWNE T028N R113W SEC-0031 E2NE T028N R113W SEC-0032 LOT 1, N2NW, SWNW 50101-00 USA EV-025991 04/01/1952 BK 89 PG 82 WY SUBLETTE T029N R113W SEC-0034 ALL 50113-00 MYRON EDGAR MILLS ET UX 05/20/1953 BK 5 PG 107 WY SUBLETTE T028N R113W SEC-0022 SESE T028N R113W SEC-0023 E/2SW, SWSW, SAID LANDS BEING NOW RESURVEYED INTO AND AS TRACT 44 50131-00 USA W-48904 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 LOT 1 (NENE - 39.78 AC), SENE T028N R113W SEC-0032 W2N2 T028N R113W SEC-0032 LOT 6 (SESE- 47.69) E2NE, NESE T028N R113W SEC-0033 SWNW 50133-00 USA EV-010270-B 10/16/1939 BK 89 PS 112 WY SUBLETTE T027N R113W SEC-0021 N2N2 50134-00 USA W-0256493 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 3, 4, NE, N2SE T028N R113W SEC-0034 LOT 1, W2NW, NWSW 50135-00 USA W-0256 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0009 W2NE 50136-00 USA EV-026191 03/01/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 SESW. SWSE 50137-00 USA W-048780 07/01/1947 BK 89 PG 89 WY SUBLETTE T027N R113W SEC-0004 LOTS 2, 3, SWNE 50138-00 USA EV-022209 06/01/1947 BK 88 PG 789 WY SUBLETTE T028N R113W SEC-0033 LOTS 1, 2 N2SW 50139-00 USA W-9653 03/10/1950 BK 89 PG 132 WY SUBLETTE T027N R113W SEC-0004 LOT 4, S2NW, N2SW, NWSE 50140-00 ST WY 0-847 09/16/1936 BK PG WY SUBLETTE T027N R113W SEC-0016 ALL 50141-00 USA EV-09561-A 06/20/1932 BK 89 PG 65 WY SUBLETTE T027N R113W SEC-0017 NE, E2NW, SE, NESW T027N R113W SEC-0020 NENE, NWNE, S2NE 50142-00 USA EV-021978 01/01/1940 BK 2 PG 173 WY SUBLETTE T027N R113W SEC-0004 SWSW T027N R113W SEC-0009 NW, E2SW, W2SE 50143-00 USA EV-07555 01/01/1940 BK 89 PG 70 WY SUBLETTE T027N R113W SEC-00094 W2SW 50144-00 USA EV-07671-A 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 SE 50145-00 USA EV-07671-B 12/29/1939 BK 89 PG 125 WY SUBLETTE T027N R113W SEC-0008 N2, N2SW, S2SW 50147-00 USA W-48907 01/01/1940 BK 89 PG 76 WY SUBLETTE T027N R113W SEC-0005 N2SE, SWNE, LOTS 2, 3, 4, S2NW, N2SW, S2S2 T028N R113W SEC-0033 SENW 50149-00 USA W-0125385 12/01/1948 BK 85 PG 599 WY SUBLETTE T028N R112W SEC-0019 LOTS 3, 4 50150-00 USA W-0125387 01/01/1950 BK 85 PG 605 WY SUBLETTE T028N R112W SEC-0030 LOT 1 50151-00 USA W-0125388 06/01/1948 BK 85 PG 621 WY SUBLETTE T028N R113W SEC-0023 NENW, NWNE, LOTS 1, 2, 3, NENE T028N R113W SEC-0024 LOTS 3 (48 AC) LOT 4 (48.77 AC) 50152-00 USA EV-022756 09/01/1946 BK 89 PG 17 WY SUBLETTE T028N R113W SEC-0014 S2NW, SW, N2NW 50153-00 USA EV-023554 01/01/1948 BK 89 PG 19 WY SUBLETTE T028N R113W SEC-0026 SESW, S2SE, LOT 1, SENW, NESW, N2SE, NE 50154-00 USA EV-024756 06/01/1948 BK 67 PG 70 WY SUBLETTE T028N R113W SEC-0023 LOTS 5, 6, 7 T028N R113W SEC-0024 LOTS 5, 6, 7, 7, 8, TRACT 46 A&B T028N R113W SEC-0025 LOTS 1, 2, 3, 4, W2E2, E2W2, SWSW, W2N2, NWSW 50155-00 USA EV-024792 07/01/1948 BK 85 PG 614 WY SUBLETTE T028N R113W SEC-0034 LOT 2 50156-00 USA W-02985 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0035 LTS 1, 2, 3, 4, 5, 6, 7, W2NE, N2NW, SWNW, N2SW, NWSE 50157-00 USA W-02985-A 06/01/1948 BK 89 PG 3 WY SUBLETTE T028N R113W SEC-0034 SENW 50158-00 USA W-046892 02/01/1957 BK 85 PG 582 WY SUBLETTE T028N R113W SEC-0034 E2N2, SWNE, N2SE, LOTS 3 & 4 50159-00 USA W-05283 02/01/1951 BK 31 PG 229 WY SUBLETTE T028N R113W SEC-0004 LOTS 5, 6, S2N2, N2SE, SESE, SWSE 50160-00 USA W-08056 09/01/1951 BK 32 PG 63 WY SUBLETTE T028N R113W SEC-0034 E2NW, NESE, NWNE 50161-00 USA W-10675 09/01/1950 BK 31 PG 274 WY SUBLETTE T029N R113W SEC-0035 W2SW, SESW, NESW 50162-00 USA W-10677 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 NESE, SENW, SESE, S2NE T029N R113W SEC-0027 NESE, SENW, SESE, S2NE 50163-00 USA W-10679 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R113W SEC-0003 S2/SW 50164-00 STATE OF WYOMING 0-11142 05/16/1951 BK 19 PG 243 WY SUBLETTE T028N R113W SEC-0005 E2SW, SE, NW (PART OF RESURVEY TRACT 54) 50165-00 ST WY 020810 06/16/1956 BK 85 PG 669 WY SUBLETTE T028N R113W SEC-0036 W2SW 50166-00 USA W-06861 07/01/1951 BK 85 PG 40 WY SUBLETTE T028N R113W SEC-0015 SENE, N2NE 50167-00 USA W-014074 06/01/1952 BK 89 PG 96 WY SUBLETTE T029N R113W SEC-0035 N2NW, SENW, SWNW 50169-00 USA W-0125384 05/01/1948 BK 31 PG 242 WY SUBLETTE T028N R113W SEC-0011 E2 T028N R113W SEC-0013 SW T028N R113W SEC-0014 SWNE, W2SE, N2NE, SENE, E2SE 50170-00 USA W-10681 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 E2NE, NESE, NWSE, S2SE, W2NE T029N R113W SEC-0026 NWNW T029N R113W SEC-0027 N2NE 50171-00 USA W-10682 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0022 NW, N2SW, S2SW T029N R113W SEC-0024 E2SE, NENW, NWNW, NWSE, SENW, SW, SWMW, SWSE, S2NE T029N R113W SEC-0025 NENW T029N R113W SEC-0027 NENW 50172-00 CHARLES P NOBLE ET UX 02/03/1954 BK 7 PG 360 WY SUBLETTE T029N R113W SEC-0011 E2NW, NE T029N R113W SEC-0012 W2NW 50173-00 USA EV-024549-A 07/01/1951 BK 22 PG 137 WY LINCOLN T026N R112W SEC-0005 THAT PORTION OF THE GREEN RIVER RIPARIAN TO LOTS 4, 5, 6, 7, 10, 11 AND 13 T026N R112W SEC-0008 THAT PORTION OF THE GREEN REIVER RIPARIAN TO LOTS 1, 2, 4, 5, 6, 7 AND 11 50174-00 USA W-20951 09/01/1947 BK9PR PG 66 WY LINCOLN T026N R112W SEC-0004 LOTS 1, 2, 3, 4, S2N2, SW4 50175-00 USA EV-022929-A 09/01/1952 BK9PR PG 206 WY SUBLETTE T027N R112W SEC-0033 NW4 50176-00 USA W-022931 11/01/1947 BK24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOTS 4 (17.01), 7 (7.50), 10 (25.29), 11 (42.73), 13 (23.59) AND SWSE T026N R112W SEC-0008 LOT 1 (12.18), 2, (19.72), 4 (32.67), 5 (20.41), 6 (18.10), AND W2NE LOT 7 (43.63), 11 (30.54) BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0029 LOTS 2 (35.76), 3 (16.18), 4 (45.23), 5 (6.90), 8 (6.23), 9 (37.63), 10 (1.67), 11 (22.05), 12 (23.76) 50177-00 USA EV-022931-A 11/01/1947 BK 24PR PG 253 WY LINCOLN T026N R112W SEC-0005 LOT 1 (36.87), SENE, E2SE T026N R112W SEC-0008 E2NE, E2SE BK 15 PG 193 WY SUBLETTE T027N R112W SEC-0028 ALL T027N R112W SEC-0029 E2SE T027N R112W SEC-0032 SENE, E2SE, NENE 50178-00 USA EV-022935 10/01/1947 BK 43 PG 242 WY LINCOLN T026N R112W SEC-0005 LOTS 5 AND 6 50180-00 USA EV-023229-A 07/01/1947 BK 89 PG 52 WY SUBLETTE T027N R112W SEC-0021 LOTS 9, 10, 11, SWSW 50181-00 USA W-20950 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0033 SE, NE4 T026N R112W SEC-0008 E2NE, E2SE 50182-00 USA W-039163 09/01/1947 BK 15 PG 206 WY SUBLETTE T027N R112W SEC-0029 THAT PORTION OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 3, 4, 5, 8, 9, 10, 11, 12 50183-01 KENNETH BARLETT, GUARDIAN 10/29/1958 BK 22 PG 349 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-02 ATHOL L STOTTS, ET UX 01/23/1956 BK 15 PG 79 WY SUBLETTE T027N R112W SEC-0029 S2NE, LOT 1 & LOT 6 50183-03 MARY MAXINE DELANEY, ET AL 01/23/1956 BK 15 PG 231 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50183-04 FLORENCE VICKREY, ET AL 01/23/1956 BK 15 PG 295 WY SUBLETTE T027N R112W SEC-0029 S2N2, LOT 1 & LOT 6 50184-01 SELMER G LARSON, RECEIVER 06/21/1956 BK 18 PG 216 WY LINCOLN T026N R112W SEC-0008 LOTS 8 (16.37), 9 (28.05), 10 (41.40), SWSW 50184-02 WILLIAM J MCGINNIS 06/21/1956 BK 18 PG 214 WY LINCOLN T026N R112W SEC-0008 LOTS 8, 9, 10, SW4SW4, BED OF GREEN RIVER RIPARIAN TO LOTS 8, 9, & 10 50185-00 BENEFICIAL OIL CO. 09/16/1959 BK 24 PG 537 WY SUBLETTE T027N R112W SEC-0017 N2NE, SENE, NENW T027N R112W SEC-0020 LOTS 1, 2 & 5, NENE, NWSE T027N R112W SEC-0021 LOTS 2 (16.93), 3 (39.25), 4 (11.04), 5 (15.73), 6 (20.24), NWNW 50186-00 M F WHELAN LIVESTOCK COMPANY 01/25/1954 BK 9 PG 63 WY SUBLETTE T027N R112W SEC-0029 INSOFAR AS LSE COVERS: LOT 7 (NW/4SE/4) T027N R112W SEC-0032 INSOFAR AS LSE COVERS: NWNE, INCLUDING RIPARIAN RIGHTS IN THE GREEN RIVER 50187-00 USA W-06206 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 E2 T030N R113W SEC-0015 N2NW, NWNE, S2N2, NENE, N2S2, SESW, S2SE 50198-00 USA W-10678 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 S/2NE, N/2SE, SESE 50213-00 USA W-23002 03/01/1970 BK 58 PG 661 WY SUBLETTE T030N R113W SEC-0008 SESW, NESW, SWSW T030N R113W SEC-0017 NW, SW 50269-00 USA W-0322521 03/01/1966 BK 294 PG 638 WY LINCOLN T026N R113W SEC-0009 SESW 50270-00 ST WY 63-11625 08/02/1963 BK 204 PG 257 WY LINCOLN T026N R113W SEC-0016 ALL 50272-00 USA W-09156B 06/01/1948 BK 17 PG 283 WY LINCOLN T026N R113W SEC-0008 NE, N2SE, SESE, E2NW T026N R113W SEC-0009 W2W2M E2NW, NESW 50274-00 USA W-020123-A 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0004 SWSW T027N R112W SEC-0005 SESE, LOT 4, S2NW, SW, N2SE, W2SE T027N R112W SEC-0009 SWSW T027N R112W SEC-0017 SE, SWNE T027N R112W SEC-0029 W2NE 50275-00 USA W-025407A 05/01/1954 BK 34 PG 635 WY SUBLETTE T027N R112W SEC-0031 LOTS 1, 2, 5, 6, 7, 8, 11, 12, E2NWNE, W2NWNE T030N R113W SEC-0017 NW, SW 50276-00 USA W-020123 04/01/1953 BK 21 PG 509 WY SUBLETTE T027N R112W SEC-0006 ALL T027N R112W SEC-0008 W2NW, SENW, SW T027N R112W SEC-0020 LOT 6, NW, N2SW, SWSW 50277-00 USA EV-023313 02/01/1948 BK286 PG 640 WY LINCOLN T026N R112W SEC-0006 SWNE 50278-00 USA EV-023313 02/01/1948 BK K286 PG 640 WY LINCOLN T026N R112W SEC-0006 SESW, NESW, SWSW 50279-00 USA W-024793 02/01/1954 BK 30 PG 138 WY LINCOLN T026N R113W SEC-0014 SENW, SW T026N R113W SEC-0022 NENE, SENE, SENW, SWNE T026N R113W SEC-0023 N2NW, LOTS 1, 2, 3, 4 50280-00 USA W-022407 05/01/1954 BK 150 PG 334 WY SUBLETTE T027N R112W SEC-0006 LOTS 3, 4, 7, 8, NENE, W2NE, NWSE, N2SWSE, SESWSE, SWSWSE 50281-00 USA W-025410 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0030 LOTS 1, 2, 5, 6, E2W2 BK 30 PG 490 WY LINCOLN T027N R112W SEC-0002 LOT 1 50282-00 USA W-025410-A 05/01/1954 BK 22 PG 22 WY SUBLETTE T027N R112W SEC-0031 LOTS 3, 4, 7, 9, NWNENW, W2SE, S2SWNE, NESWNE LOT 10, E2NENW, SWNENW, SENW, NWSWNE, E2SW 50283-00 USA EV-025440 03/01/1950 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0007 NE, W2SE, E2SE T027N R112W SEC-0018 S2NE, SE, N2NE 50284-00 USA EV-025440-A 03/01/1955 BK 22 PG 32 WY SUBLETTE T027N R112W SEC-0019 E2 50285-00 USA W-033951 07/01/1955 BK 296 PG 257 WY SUBLETTE T026N R113W SEC-0010 S2NE 50286-00 USA W-036054 04/01/1956 BK 21 PG 292 WY SUBLETTE T027N R113W SEC-0027 NWNE 50287-00 USA W-038682 09/01/1956 BK 288 PG 52 WY LINCOLN T026N R113W SEC-0002 LOTS 2, 3, 5, 6, 12 BK 70 PG 151 WY SUBLETTE T027N R113W SEC-0035 W/2 50288-00 USA W-03682-A 09/01/1956 BK 88 PG 52 WY LINCOLN T026N R113W SEC-0014 LOTS 3, 4 50290-00 USA W-047412 09/01/1958 BK 88 PG 123 WY SUBLETTE T027N R112W SEC-0009 LOT 1 50291-00 USA W-0499597412 06/01/1957 BK 23 PG 512 WY LINCOLN T026N R112W SEC-0006 THAT PORTION OF THE BED OF GREEN RIVER RIPARIAN TO LOT 7 50292-00 USA W-050961 09/01/1957 BK 24 PG 335 WY LINCOLN TO26N R112W SEC-0006 LANDS COVERING ALL OF THE BED OF THE GREEN FIVER LYING IN LOT 6 BETWEEN THE MEAN HIGH WATER MARKS THEREOF, EXCEPTING THAT PORTION OF THE SAID RIVER BED WHICH LIES RIPARIAN TO LOT 7 OF SEC 6. SAID LANDS BEING ONLY THAT PORTION OF THE BED OF THE GREEN RIVER APPURTENANT TO LOT 6. 50293-00 USA W-052064 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0007 LOT 5 T026N R112W SEC-0018 LOT 1, 2, 3, 50294-00 USA W-052065 02/01/1948 BK249 PG 232 WY LINCOLN T026N R112W SEC-0006 LOT 1, 2, 3, 4, 5, 6, 7, 9 50295-00 USA W-05751 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0007 LOTS 1, 2, 3, 4, E2W2 T027N R112W SEC-0018 LOT 1, 2, E2NW, LOTS 3, 4, E2SW 50296-00 USA W-05751-A 06/01/1951 BK 22 PG 39 WY SUBLETTE T027N R112W SEC-0019 LOT 1, 2, 3, 4, E2W2 50297-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0030 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 2, 4, 7, 8 50298-00 USA W-059584 03/01/1956 BK 18 PG 217 WY SUBLETTE T027N R112W SEC-0031 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, 5, 6, 7, 8 11, 12 50299-00 USA W-059585 07/01/1947 BK 85 PG 49 WY SUBLETTE T027N R112W SEC-0009 LOTS 2 (6.59), 3 (10.11) T027N R112W SEC-0020 LOTS 3, (4.94), 4 (20.40) 50300-00 USA W-066369 07/01/1988 BK305 PG 26 WY LINCOLN T026N R113W SEC-0015 S/2 50301-00 USA W-066370 10/11/1958 BK305 PG 30 WY LINCOLN T026N R112W SEC-0022 N2NW, NWNE, SWNW, NWSW 50302-00 USA EV-07798-E 09/01/1954 BK 30 PG 22 WY LINCOLN T026N R113W SEC-0002 LOT 4 (41.5) T026N R113W SEC-0010 SE T026N R113W SEC-0011 N2NW, SENW, SW, W2NE, W2SE, LOTS 1, 2, 3, 4 T026N R113W SEC-0014 N2NW, SWNW, W2NE, W2SE, LOTS 1, 2 T026N R113W SEC-0015 N2N2 50303-00 USA EV-08051-B 04/01/1958 BK 86 PG 278 WY SUBLETTE T027N R113W SEC-0027 E2NE, E2SWNE 50304-00 ST WY 0-11135 05/16/1951 BK 22 PG 430 WY LINCOLN T026N R113W SEC-0013 ALL (RES PT LOT 37) 50305-00 ST WY 0-1137 05/16/1951 BK 22 PG 433 WY LINCOLN T026N R113W SEC-0024 S2N2 (RES LOT 39) 50306-00 ST WY 0-11141E 05/16/1951 BK 21 PG 272 WY SUBLETTE T027N R113W SEC-0036 ALL 50307-00 ANDERSON L MCGINNIS, ET UX 12/26/1956 BK 16 PG 336 WY SUBLETTE T027N R112W SEC-0003 PARTS OF LOTS 3 & 4 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT ON THE EAST LINE OF SAID LOT 3, 325' SOUTH OF THE OLD PARTITION FENCE, THENCE ALONG SAID FENCE 89 DEGREES WEST TO THE WEST BOUNDARY OF SAID LOT 4, THENCE SOUTH TO THE SW CORNER OF SAID LOT 4, THENCE EAST TO THE SE CORNER OF SAID LOT 3, THENCE NORTH TO THE PLACE OF BEGINNING. THAT PART OF LOT 5 DESCRIBED AS FOLLOWS: COMMENCING AT A POINT 1635' SOUTH OF THE QUARTER SECTION CORNER ON THE NORTH LINE OF SAID SECTION AND RUNNING THENCE EAST ALONG THE MCGINNIS MICKELSON PARTITION FENCE TO THE GREEN RIVER, THENCE IN A SOUTHEASTERLY DIRECTION ALONG GREEN RIVER TO THE EAST AND WEST QUARTER SECTION LINE IN SAID SECTION 3, THENCE WESTERLY ALONG SAID EAST AND WEST QUARTER SECTION LINE TO THE CENTER OF SAID SECTION 3, THENCE NORTH TO THE PLACE OF BEGINNING. E2SW, NWSW, SWSW, S2NW, LOTS 8 & 9 T027N R112W SEC-0004 SE, SESW, S2NE, LOT 1 T027N R112W SEC-0008 E2NE T027N R112W SEC-0009 NW, N2NE, N2SW, SESW, SWNE, S2SE, LOTS 1, 4, 5 T027N R1112W SEC-0010 LOTS 2, 3, 7 50308-00 ST WY 0-11134 05/16/1951 BK 22 PG 439 WY LINCOLN T026N R113W SEC-0012 ALL 50309-01 SELMER G LARSON 01/08/1957 BK 20 PG 434 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, W2, SE T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0018 LOT 4, E2W2, E2 T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, NESW, NE4, N2SE4 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW 50309-02 NEWT SIMS LARSON 12/15/1956 BK 20 PG 234 WY LINCOLN T026N R112W SEC-0017 S2S2 T026N R112W SEC-0018 PART SESE E OF HWY 189 T026N R112W SEC-0019 PART E2NE, NESE E HWY 189 T026N R112W SEC-0020 N2, N2S2 T026N R112W SEC-0021 W2NW, NWSW, LOTS 2, 3, 6 50309-03 WILLIAM J MCGINNIS ET UX 11/13/1956 BK 19 PG 394 WY LINCOLN T026N R112W SEC-0007 SWSE, SESW, E2SE4 T026N R112W SEC-0017 LOTS 2, 3, 4, N2SE, NW, N2SW T026N R112W SEC-0018 W2NE, E2NW, NESW, SESW, LOT 4, SWSE, NE4, N2SE T026N R112W SEC-0019 LOTS 1, 2, 3, E2NW, W2NE, NESW, NWSE, ALSO ALL THAT PART OF THE SE4SE4 SEC 18; E2NE4, NE4SE4, SEC. 19 LYING WEST OF STATE HWY 287, CENTER LOCATION OF SAID HWY BEING LOCATED IN SAID SE4SE4, SECTION 18 AND E2NE4, NE4SE4, SEC. 19 AS FOLLOWS: 958 FEET WEST OF NE CORNER OF SE4SE5, SEC. 18; 701 FEET WEST OF NE CORNER, SEC. 19; 554 FEET WEST OF EAST SECTION LINE ALONG THE HALF SECTION LINE OF SEC. 19; AND 177 FEET WEST OF SE CORNER OF SEC. 19, CONTAINING 1,375.10 ACRES, MORE OR LESS. 50310-00 ST WY 0-11216B 05/16/1951 BK 3 PG 468 WY SUBLETTE T027N R112W SEC-0016 W2 50311-00 USA W-048781 06/01/1956 BK 24 PG 339 WY SUBLETTE T0276N R113W SEC-0035 E/2 50312-00 ST WY 0-11136 05/16/1951 BK 22 PG 436 WY LINCOLN T026N R112W SEC-0024 N2N2 (RES LOT 38) NWSW (RES LOT 40) 50318-00 GEORGE E YEAMAN ET UX 11/29/1956 BK 20 PG 248 WY LINCOLN T026N R112W SEC-0007 W2NE, NENE, LOT 3 T026N R112W SEC-0008 LOT 3, EXCEPT HWY TRACT 50319-00 WINSTON H ALLEMAN ET UX 02/26/1959 BK 32 PG 445 WY LINCOLN T026N R112W SEC-0005 LOT 12 T026N R112W SEC-0006 THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLAT NO. 1 FOR SW4SE4 AND NW4SE4 SECTION 6-26-112 LINCOLN COUNT LOT 2: ALL LINCOLN COUNT LOT 3: ALL LINCOLN COUNTY LOT 8: ALL, EXCEPT FOR THE FOLLOWING DESCRIBED PARCELS: BEGINNING AT THE SOUTH WEST CORNER OF THE SOUTH WEST QUARTER OF THE SOUTH EAST QUARTER (SW4SE4) OF SECTION SIX THENCE EAST ON THE SECTION LINE BETWEEN SAID SECTIONS SIX (6) AND SEVEN(7), TOWNSHIP TWENTY-SIX NORTH, RANGE ONE HUNDRED TWELVE WEST OF THE 6TH P.M. IN WYOMING, A DISTANCE OF 1043.35 FEET; THENCE NORTH A DISTANCE OF 835 FEET; THENCE WEST A DISTANCE OF 1043.35 FEET; THENCE SOUTH ON THE MID-SECTION LINE OF SAID SECTION SIX A DISTANCE OF 835 FEET TO THE POINT OF BEGINNING. TWO AND NINETY SEVEN HUNDREDTHS ACRES MORE OR LESS, STARTING FROM A POINT 1043.35 FEET EAST AND 835 FEET NORTH OF THE SOUTH WEST CORNER OF LINCOLN COUNTY, LOT NUMBER 8 AS SHOWN UPON LINCOLN COUNTY METES AND BOUNDS MAP NUMBER ONE, SECTION 6, TOWNSHIP 26 NORTH, RANGE 112 WEST; THENCE IN A NORTHERLY DIRECTION PARALLEL TO THE WEST BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 TO THE NORTH BOUNDARY OF SAID LOT 8; THENCE WEST ALONG THE NORTH BOUNDARY LINE OF SAID LOT NUMBER 8 TO THE CORNER THAT IS 566.31 FEET FROM ITS WESTERN BOUNDARY, THENCE IN A SOUTHERLY DIRECTION PARALLEL TO THE WESTERN BOUNDARY OF LINCOLN COUNTY LOT NUMBER 8 FOR A DISTANCE OF 271.35 FEE; THENCE IN AN EASTERLY DIRECTION TO THE POINT OF BEGINNING. LINCOLN COUNTY LOT 21: ALL LA BARGE TOWN LOTS 5-12; INCLUSIVE IN BLOCK 1 51% OF LOTS 1 & 2, AND ALL OF LOTS 5-20, INCLUSIVE IN BLOCKS 3 OF THE SECOND ADDITION AND LOT 23, BLOCK 1 OF THE ORIGINAL TOWNSITE. THE FOLLOWING PARCELS SHOWN AND DESCRIBED ON LINCOLN COUNTY METES AND BOUNDS PLATE NO. 2, FOR LOTS 8 & 11, SECTION 6-26-112 LINCOLN COUNTY LOT 19: ALL LINCOLN COUNTY LOT 20: ALL 50320-01 CYRIL HOUSLEY ET UX 11/14/1956 BK 19 PG 398 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, NWSE, SENW, NESW 50320-02 AUGUSTA B MARX 11/19/1956 BK 19 PG 475 WY LINCOLN T026N R112W SEC-0007 LOT 2, 4, SENW, NWSE, NESW 50322-00 ST WY 0-22646T UX 11/16/1958 BK 35 PG 543 WY LINCOLN T026N R112W SEC-0001 ALL OF ORIGINAL SECTION 1 50324-00 JOHN E MARX ET UX 11/01/1956 BK 19 PG 353 WY LINCOLN T026N R112W SEC-0006 E2SW, LOT 10 T026N R112W SEC-0007 LOT 1, NENW 50325-00 USA W-033913 11/01/1956 BK 22 PG 419 WY SUBLETTE T028N R112W SEC-0033 W2NW, NWSE, NENE, S2NE, E2NW, NWNE, SWSE, E2SE 50329-01 WY STATE HWY COMMISSION 08/22/1958 BK 32 PG 379 WY LINCOLN T026N R112W SEC-0006 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 1: E2SE PARCEL 2: LOT 11, SWSE T026N R112W SEC-0007 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 3: E2NE PARCEL 4: E2SE PARCEL 5: E2SE, SWSE PARCEL 6: NWSE PARCEL 7: LOT 3, NENE, W2NE PARCEL 8: W2NE PARCEL 9: NENW, LOT 1 PARCEL 10: PARCEL OF LAND INCLUDED WITHIN THE RIGHT OF WAY OF THE STAT HIGHWAY PROJECT L. N. -10 & F.A. PROJECT 158A, KNOWN AS THE KEMMERER-MARBLETON ROAD, SAID RIGHT-OF- WAY BEING 80' WIDE AND LYING 40' ON EITHER SIDE AND BEING EQUIDISTANT FROM A CERTAIN CENTER LINE DESCRIBED BY COURSES AND DISTANCES AS FOLLOWS: BEGINNING AT A POINT DESIGNATED IN THE FIELD NOTES OF THE SURVEY OF THE ABOVE MENTIONED HIGHWAY AS STATION 1276 40.0, SAID POINT BEING ON THE SOUTH BOUNDARY LINE OF NESE OF SECTION 19-26N-112W, 6TH P.M.; AND N 17 DEGREE 11' W A DISTANCE OF 1129.9' FROM POINT WHICH IS N 31 DEGREE 48' W A DISTANCE OF 337.3' FROM A POINT WHICH IS EAST A DISTANCE OF 250' FROM THE SE CORNER OF SECTION 19, AFORESAID; THENCE N 17 DEGREE 11' W A DISTANCE OF 1076.2' TO A POINT OF AN 8 DEGREE 00' CURVE TO THE RIGHT, THE RADIUS OF WHICH IS 716.2', THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 16 DEGREE 00', A DISTANCE OF 200'; THENCE N 1 DEGREE 11; W A DISTANCE OF 2142.3'; THENCE N 1 DEGREE 21' E 145.2' TO POINT OF A 10 DEGREE 00' CURVE TO THE LEFT, THE RADIUS OF WHICH IS 573'; ALONG SAID CURVE THROUGH AN ANGLE OF 21 DEGREE 40' A DISTANCE OF 216.7; THENCE N 20 DEGREE 19' W A DISTANCE OF 484.3" TO A POINT OF A 6 DEGREE 00' CURE TO THE RIGHT, THE RADIUS OF WHICH IS 954.9'; THENCE ALONG SAID CURVE THROUGH AN ANGLE OF 11 DEGREE 23' A DISTANCE OF 189.7; THENCE N 8 DEGREE 56' W A DISTANCE OF 2582.7' TO THE POINT OF A 5 DEGREE 00' CURVE TO THE RIGHT, THE RADIUS OF WHICH IS 1145.9'; THENCE ALONG SAID CURVE, THROUGH AN ANGLE OF 9 DEGREE 11' A DISTANCE OF 183.7'; THENCE N 0 DEGREE 15' E A DISTANCE OF 4889.2, THE END, WHICH IS STATION 1397 50 OF SAID SURVEY, WHICH POINT IS ON THE E & W CENTER LINE OF SECTION 7, 26N-112W OF THE 6TH P.M. T026N R112W SEC-0018 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: E2SE, E2NE PARCEL 5: NE T026N R112W SEC-0019 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NESE, E2NE PARCEL 5: NENE PARCEL 10: SEE METES AND BOUNDS DESCRIBED IN SECTION 7 T026N R112W SEC-0020 STATE HIGHWAYS CROSSING FOLLOWING LANDS: PARCEL 4: NWSW 50343-00 USA W 05749 05/01/1951 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0010 LOT 1, NENE, S2NE T027N R112W SEC-0011 NE T027N R112W SEC-0012 S2N2, SE T027N R112W SEC-0013 E2 50344-00 USA W-066702 07/01/1947 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 LOT 4 AND 5 50346-00 USA W-278782 04/01/1971 BK 46 PG 707 WY SUBLETTE T027N R112W SEC-0001 SE T027N R112W SEC-0012 N2NE 50347-00 USA EV-023053 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2NE 50348-00 USA EV-023053-A 01/01/1948 BK 84 PG 704 WY SUBLETTE T027N R112W SEC-0015 E2SE 50349-00 USA EV-023057 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0010 SE T027N R112W SEC-0015 W2NE 50350-00 USA EV-023057-A 01/01/1948 BK 89 PG 145 WY SUBLETTE T027N R112W SEC-0015 W2SE 50351-00 USA EV-023066 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0010 E2SW, LOTS 6, 8 T027N R112W SEC-0015 E2NW, SWNW, LOT 1 50352-00 USA EV-023066-A 01/01/1948 BK 89 PG 105 WY SUBLETTE T027N R112W SEC-0015 SW 50353-00 USA W-053031 09/01/1957 BK 87 PG 702 WY SUBLETTE T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER RIPARIAN TO LOT 2 MORE FULLY DESC. BY METES & BOUNDS IN LSE. 50354-00 USA W-066701 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0010 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 4, 5, 6, 8 T027N R112W SEC-0015 PORTION OF BED OF GREEN RIVER THAT IS RIPARIAN TO LOT 1 ALL ACRES SHOWN IN SEC 10 50355-00 USA W-07828 08/01/1951 BK 69 PG 587 WY SUBLETTE T028N R112W SEC-0003 LOTS 7 (NENW), 8 (NWNW), S2NW, N2SW 50362-00 USA W-01332 05/01/1950 BK 31 PG 266 WY SUBLETTE T029N R113W SEC-0026 SESE, SWSE, N2SE, S2NE, SENW 50365-00 USA EV-013494 12/31/1938 BK 31 PG 333 WY SUBLETTE T029N R113W SEC-0014 SW, W2SE, S2NW, SWNE T029N R113W SEC-0023 E2 50380-00 USA W-60577 11/01/1977 BK 73 PG 208 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1, 2, 3, 4, E2, E2W2 T028N R111W SEC-0031 NE, E2SE T027N R111W SEC-0032 W2 50384-00 USA W-62791 05/01/1978 BK 65 PG 556 WY SUBLETTE T028N R111W SEC-0025 E2 LOT 1 (20.64 AC) LOT 3 (41.1 AC) 40.82 AC) LOT 6 (30.22 AC) LOT 7 (40.54 AC), SESWNE, SENESW, SESW, W2SE T028N R111W SEC-0031 LOTS 1 (NWNW), 2(SWNW), E2NW, W/2SE LOTS 3 (NWSW), 4 (SWSW), E2SW 50431-00 USA EV-022769-A 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0001 LOTS 3, 4, S2NW, SW T029N R113W SEC-0002 LOTS 1, 2, 3, 4, S2NE SENW, S2 50432-00 USA EV-0177710-B 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0028 E2 T030N R113W SEC-0034 N2SW, SE, SESW 50434-00 USA EV-017710-A 12/31/1938 BK 54 PG 228 WY SUBLETTE T030N R113W SEC-0034 SWSW 50435-00 USA EV-022769 12/31/1938 BK 88 PG 767 WY SUBLETTE T029N R113W SEC-0003 LOTS 1 32.83), 2 (32.18) 3 (31.53), 4 (30.88) S/2N/2, SW, S/2SE, NWSE T029N R113W SEC-0004 LOTS 1 (31.11), 2(32.20)M 3 (33.30), S/2NE, SENW, NESW, N/2SE T030N R113W SEC-0033 E/2, E/2W/2 55787-01 KATHLEEN ANN MILLER 08/31/1986 BK 77 PG 548 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-02 ROBERT M MILLER JR ET UX 08/13/1986 BK 77 PG 554 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-03 MATTHEW DANIEL MILLER 08/13/1986 BK 77 PG 550 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-04 PATRICIA M ROBERTS ET VIR 08/13/1986 BK 77 PG 552 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-05 PRISCILLA KYSAR ET VIR 08/13/1986 BK 77 PG 546 WY SUBLETTE T029N R113W SEC-0011 W2NW 55787-06 ALBERT E SCHWABACHER ET AL 04/13/1988 BK 81 PG 655 WY SUBLETTE T029N R113W SEC-0011 W2NW 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW T029N R113W SEC-0003 NESE 57790-00 USA W-01763 03/01/1986 BK274 PG 531 WY LINCOLN T029N R112W SEC-0013 LOTS 1 & 2 57808-00 USA EV-026240 11/01/1950 BK305 PG 95 WY LINCOLN T026N R113W SEC-0023 NWNE 57809-00 USA W-059091 08/01/1949 BK 89 PG 139 WY SUBLETTE T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 1, 2, & 3 T027N R112W SEC-0009 THAT PORTION OF THE BED OF THE GREEN RIVER THAT IS RIPARIAN TO LOTS 3 & 4 57810-00 USA W-025765 06/01/1954 BK305 PG 89 WY LINCOLN T0276 R112W SEC-0002 LOTS 7, 8, 9, 10, & 11 57821-00 JOSEPH W KRALL 03/23/1989 BK 82 PG 551 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/SW 57821-02 SUSAN K DONALDSON ET VIR 03/23/1989 BK 82 PG 643 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-03 SALLY ORR, ET VIR 03/23/1989 BK 82 PG 641 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-04 JUDY BETKA, ET VIR 03/23/1989 BK 82 PG 645 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-05 NANCY JO T KNADLER, ET VIR 03/22/1989 BK 82 PG 549 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-06 TED E MILLER 03/29/1989 BK 82 PG 635 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-07 FRANK T MILLER 03/29/1989 BK 82 PG 637 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57821-08 MARILYN JAMES, ET VIR 03/31/1989 BK 82 PG 639 WY SUBLETTE T027N R113W SEC-0032 SESE T027N R113W SEC-0033 S/2SW 57964-00 USA WYW-034923 10/01/1950 BK314 PG 254 WY LINCOLN T0267N R113W SEC-0008 SWSE 75007-00 USA WY-088276 07/01/1961 BK 50 PG 61 WY LINCOLN T026N R113W SEC-0011 SWNW 75012-00 USA EV-021976 04/01/1949 BK 18 PG 130 WY LINCOLN T026N R113W SEC-0005 LOT 3, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 6, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75013-00 USA EV-025792 09/01/1946 BK314 PG 218 WY LINCOLN T026N R113W SEC-0005 LOT 1, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 7, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. LOT 8, INSOFAR AS THE ABOVE LANDS COVER THE RIGHTS FROM THE SFC TO THE STRAT EQUIVALENT OF THE BASE OF HILLARD (BAXTER SHALE) AS DEFINED @ 6260 FEET IN THE MOBIL T-51X-5 WELL, LOCATED IN LOT 2 OF SEC 5 TOWNSHIP 26 NORTH, RANGE 113 WEST, "Excepting AND RESERVING UNTO MOBIL" THE STRAT EQUIVALENT OF INTERVAL BETWEEN 4758' AND THE FAULT, @5425' LOCATED IN THE MOBIL T84-6-G WELL, LOCATED IN LOT 10 OF SECTION 6, TOWNSHIP 26 NORTH, RANGE 113 WEST. 75021-00 USA W-104985 08/01/1987 BK263 PG 159 WY LINCOLN T026N R111N SEC-0008 N2NW, SENW 75022-00 USA WYW-102101 11/01/1986 BK263 PG 163 WY LINCOLN T026N R111N SEC-0008 N2NW, SWNW, SWSW T026N R111N SEC-0022 SWNW, S2 T026N R111N SEC-0028 NENE 75047-00 USA WYW-11667 12/01/1988 BK314 PG 241 WY LINCOLN T026N R114W SEC-0011 NE, S2 T025N R114W SEC-0012 LOTS 1-12, W/2 T025N R114W SEC-0013 LOTS 1-12, W/2 75052-00 CARL TAYLOR, ET UX 04/22/1959 BK 34 PG 187 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS: BLOCK 1: LOTS 3 & 19 = .13774 AC BLOCK 3: LOTS 1, 2, 3, 4, 8, 9, 10, 11 AND 12 = .61983 AC BLOCK 12: LOTS 1,2,3,4,5,6,7, AND 8 -.55096 ACRES 75054-00 C J PAYNE, ET UX 03/07/1959 BK 34 PG 183 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 27,28,29 BLOCK 5: LOTS 15,16 BLOCK 7: LOT 15 CONTAINING .41322 ACRES 75055-00 JAMES A DEGRAW, ET UX 03/07/1959 BK 34 PG 181 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOTS 6,7,8,9,10 BLOCK 11: LOT 1 CONTAINING .41322 ACRES 75056-00 CECIL J STUDT, ET UX 03/07/1959 BK 34 PG 179 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK A: RIVER VIEW ADDITION LOT 3 BLOCK C: RIVER VIEW ADDITION LOTS 1,2,3,4,5,6,7,8 BLOCK 5: LOTS 1,2,3,4,5,6,7,8,17,18,19,20,21,22,23 CONTAINING 1.65309 ACRES 75057-00 CYRIL HOUSLEY, ET UX 03/07/1959 BK 34 PG 177 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS SECOND ADDITION, BLOCK 1: LOTS 3 AND 4 CONTAINING .289254 ACRES 75058-01 THERESA R DECKER 03/07/1959 BK 34 PG 175 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 3 & 4 BLOCK 6: SOUTHERLY 8 FEET OF LOT 2 75059-00 WM R DEGRAW, ET UX 03/12/1959 BK 34 PG173 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 13 & 14 CONTAINING .13774 ACRES 75060-00 ROBERT A DEGRAW, ET UX 03/12/1959 BK 34 PG 171 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 10: LOTS 1,2,3 CONTAINING .20661 ACRES 75061-00 MARIE F IVERSON 03/12/1959 BK 34 PG 169 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 23,24,25, AND 26 CONTAINING .27548 ACRES 75062-00 NEIL HACKLIN, ET UX 03/18/1959 BK 34 PG 167 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK B: LOTS 13,14,15, AND 16 = .27598 AC 75063-01 ELLIS E ALEXANDER, ET UX 03/18/1959 BK 34 PG 165 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 1,2,3,4,5,6, AND 7 CONTAINING .48209 ACRES 75063-02 FRANK ZAGAR, ET UX 07/15/1959 BK 41 PG 104 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 3,4,5,6, AND 7 75064-00 GERALD C HALE, ET UX 03/18/1959 BK 34 PG 163 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 27, 28, 29, 30, 31 AND 32 CONTAINING .41322 ACRES 75065-00 JOHN E GAULT, ET UX 03/20/1959 BK 34 PG 161 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 8,9, AND 10 CONTAINING .20661 ACRES 75066-00 JOHN EDLUND, ET UX 03/20/1959 BK 34 PG 159 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 8-10 .20661 ACS. BLOCK 10: LOTS 11-14 AND 16 .34435 ACS. 75067-00 WALTER J CRANOR, ET UX 03/20/1959 BK 34 PG 157 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 9-11 .20661 ACS. BLOCK 8: LOTS 11-15 .34435 ACS 75068-00 HOLGER JOHNSON, ET UX 03/20/1959 BK 34 PG 155 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 13-16 .27548 ACRES 75069-00 JESSE R GAULT, ET UX 03/21/1959 BK 34 PG 153 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 5,6,7, AND 8 CONTAINING .27548 ACRES 75070-00 PETE SUNDGREN, ET UX 03/23/1959 BK 34 PG 151 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 6,7 & 8; .20661 AC. 75071-00 NORMAN KIEFFER, ET UX 03/23/1959 BK 34 PG 149 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 4 & 5; .13774 AC. 75072-00 ARVEL A DAVID, ET UX 03/23/1959 BK 34 PG 147 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 6: LOTS 20-22 .20661 ACRES 75073-00 ERIC WALLIN 03/23/1959 BK 34 PG 145 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOTS 12-13 .13774 ACS. 75074-00 JOHN PEARSON 03/23/1959 BK 34 PG 143 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOT 6 .06887 ACS. 75075-00 DONALD L STUDT, ET UX 03/23/1959 BK 34 PG 141 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK A LOTS 7-11 .34435 ACS. 75076-00 GEORGE VICKREY, ET UX 03/25/1959 BK 34 PG 139 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 22-26 .34435 ACRES BLOCK 6: LOTS 18-19 .13774 ACRES BLOCK 7: LOTS 1-2 .13774 ACRES 75077-00 NELS OSTROM 03/26/1959 BK 34 PG 137 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 10 .06887 ACRES 75078-00 JOHN WESTERLUND 03/26/1959 BK 34 PG 135 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2, LOT 9 .06887 ACS. 75079-00 SAM OHME 03/26/1959 BK 34 PG 133 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 14; .06887 AC. 75080-00 RALPH V WHITE, ET UX 03/26/1959 BK 34 PG 131 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK E: LOTS 9,10,12,13; .309915 AC. 75081-00 CARL KULINSKY, ET UX 03/26/1959 BK 34 PG 127 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 1&2; .13774 AC. 75082-00 C E TALCOTT, JR, ET UX 03/26/1959 BK 34 PG 129 WY LINCOLN TO26N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOT 26; .06887 AC. 75083-00 OLIVER E GREGORY, ET UX 03/30/1959 BK 34 PG 125 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOTS 8,9,10,24,25; .34435 AC. 75084-00 J. THOMAS HALL, ET UX 03/30/1959 BK 34 PG 123 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOTS 27,28 & 29; .20661 AC. 75085-00 PETE M GOLICH, ET UX 03/30/1959 BK 34 PG 121 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1, LOTS 1 AND 2 .13774 ACS. 75086-00 VINCENT A GUYETTE 03/30/1959 BK 34 PG 105 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK B LOTS 11 & 12 .13774 ACS. 75087-00 AARON NEALE JONES, ET UX 03/26/1959 BK 34 PG 119 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION. BLOCK D LOTS 1,2,3,4 .27548 ACS 75088-00 ALVIN VALLETT, ET UX 04/02/1959 BK 34 PG 117 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 11: LOTS 2,3,4; .20661 AC. 75089-01 LESLIE C VASEY, ET UX 04/06/1959 BK 34 PG 115 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 7: LOT 3; .06887 AC SECOND ADDITION, BLOCK 3: LOTS 1 & 2; 1.61 AC. 75090-00 SCHOOL DISTRICT NO. 1 04/13/1959 BK 34 PG 113 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 8: LOTS 1,2,3,4,5,6,7; .48209 AC. 75091-00 VIRGIL V BAILEY, ET UX 03/07/1959 BK 34 PG 97 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 5: LOT 14; .06887 AC. BLOCK 6: LOTS 5,6,7,8,9 AND 10; .41322 AC. BLOCK 7: LOT 16; .06887 AC. 75092-00 DON WAGNER, ET UX 04/20/1959 BK 34 PG 111 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 30, 31 & 32; .20661 AC. 75093-00 JIMMY DE GRAW, ET UX 04/06/1959 BK 33 PG 419 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK D: LOTS 5 & 6; .13774 AC. 75094-00 VELMA WILSON, ET AL 04/20/1959 BK 34 PG 109 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 4: LOT 11; .06887 AC. 75095-00 HERMAN PIZ, ET AL 04/22/1959 BK 34 PG 107 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 3; LOTS 13 & 14; .41322 AC. 75096-00 GORDON GUYETTE, ET UX 06/02/1959 BK 34 PG 103 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK D: LOT 7; .06887 AC. 75097-00 ALEX J BERTAGNOLLI 05/09/1959 BK 34 PG 99 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOTS 1,2,3,17,18,19,20 & 21; .55096 AC. 75098-00 PAUL I BERTAGNOLLI, ET UX 06/04/1959 BK 34 PG 101 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 2: LOT 4 & 5; .13774 AC. 75099-01 C.J. YATES 10/31/1959 BK 41 PG 98 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS BLOCK 1: LOT 26 75100-00 LEO MANSKE, ET UX 10/12/1959 BK 41 PG 100 WY LINCOLN T026N R112W SEC-0006 TOWNSITE OF LABARGE (FORMERLY TULSA) THE FOLLOWING LOTS RIVER VIEW ADDITION BLOCK A: LOTS 12,13,14 & 16 75110-00 USA WYW-124999 10/01/1991 BK303 PG 145 WY LINCOLN T025N R112W SEC-0022 ALL 75148-00 USA WYW-125960 01/01/1992 BK314 PG 43 WY LINCOLN TO25N R112W SEC-0024 LOT 1 75158-00 USA WY-42788 01/01/1974 BK314 PG 223 WY LINCOLN TO25N R112W SEC-0024 W2NE, W2SE, LOTS 2,3,4 T025N R112W SEC-0025 N2NW, SENW, SW, SWNW, W2NE, W2SE, LOTS 1,2,3,4 75174-00 USA EV-07675(C) 11/01/1965 BK 88 PG 535 WY SUBLETTE T027N R113W SEC-0034 E2E2 BK311 PG 679 WY LINCOLN T026N R113W SEC-0003 LOT 1 75175-00 USA EV-07798(C) 09/01/1964 BK311 PG 221 WY LINCOLN T026N R113W SEC-0003 SWSE T026N R113W SEC-0010 W2SW 75176-00 USA EV-07798(D) 09/01/1964 BK311 PG 226 WY LINCOLN TO26N R113W SEC-0003 E2SE, LOTS 8 AND 9 T026N R113W SEC-0010 E2SW, N2NE 75177-00 USA EV-08051(A) 02/01/1948 BK 88 PG 511 WY SUBLETTE T027N R113W SEC-0027 NENW, W2SWNE 75178-00 USA EV-024168 11/01/1947 BK 36 PG 108 WY SUBLETTE T027N R113W SEC-0027 NWSE 75179-00 USA WY-040934 06/01/1956 BK 36 PG 222 WY SUBLETTE T027N R113W SEC-0027 NESE 75180-00 USA WY-041447 06/01/1956 BK 36 PG 227 WY SUBLETTE TO27N R113W SEC-0027 SESE 75181-00 USA WY-088274 07/01/1961 BK 50 PG 67 WY LINCOLN T026N R113W SEC-0002 SW 75182-00 USA WY-088275 07/01/1961 BK 50 PG 64 WY LINCOLN T026N R113W SEC-0002 W2SE, LOTS 13, 14 50002-00 ENGER K CHRISMAN 06/18/1947 BK 5 PG 3 WY SUBLETTE T029N R113W SEC-0010 SENE, NWSE 50004-00 USA W-10676 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0013 W/2 SW/4 S/2 NW/4, SW/4 NE/4, NE/4 SW/4 T029N R113W SEC-0023 W/2 W/2 50012-00 CLIFTON FEAR, ET AL 04/12/1955 BK 11 PG 449 WY SUBLETTE T029N R113W SEC-0009 E2SW, SE T029N R113W SEC-0010 SWNW, SWSE, SW T029N R113W SEC-0015 N2N2 50023-00 USA W-05689 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 W/2SWSW, E/2SWSW, SESW 50025-00 USA W-17208 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0032 LOTS: NE PART OF 17, 18, 19, 20 ALL LOT 17 EXCEPT NE 50030-00 USA W-21124 06/01/1951 BK 34 PG 174 WY SUBLETTE T030N R113W SEC-0004 LOTS 3, 4 T030N R113W SEC-0005 LOT 1, SENE, SW LOTS 2,3,4, SWNE, S2NW T030N R113W SEC-0006 SENE, NESE, LOTS 1,2, SWNE 50032-00 USA W-02736 12/01/1950 BK 33 PG 343 WY SUBLETTE T031N R113W SEC-0028 SWNW, NWSW T031N R113W SEC-0029 N2, SE, SW T031N R113W SEC-0031 E2NE, NESE LOTS 1-4, E2W2, W2NE, S2SE, NWSE T031N R113W SEC-0032 W2, W2SE, E2E2, W2NE T031N R113W SEC-0033 NWNW, S2NW, SW, SWNE, SE 50034-00 USA W-05958 07/01/1951 BK PG WY LINCOLN T025N R113W SEC-0031 S2 LOT 3, LOT 4, W2 LOT 5, SWNESW N2 LOT 3, E2 LOT 5, N2NESW, SENESW 50035-00 EDGAR F HERSCHLER ET UX 09/19/1953 BK 5 PG 398 WY LINCOLN T024N R114W SEC-0000 RESURVEY TRACT 50 BEING THE WEST 3/4 AND RESURVEY TRACT 55 BEING ALL RESURVEY TRACT 49 BEING THE WEST 40 ACRES 50036-00 ARNOLD A LARSON ET UX 09/18/1953 BK 5 PG 361 WY LINCOLN T024N R114W SEC-0000 TRACT 46-B (ORIGINALLY SESW SEC. 2) TRACT 45 BEING THE CENTER 1/3 (ORIGINALLY THE NWNW SEC. 11) TRACT 50 BEING THE MOST EASTERLY 1/4, ORIGINALLY SWNE SEC. 3 (42.79 AC) PORTION OF TRACT 48, ORIGINALLY SENE SEC. 3 (41.83 AC) TRACT 45 BEING THE MOST WESTERLY 1/3, ORIGINALLY NENE SEC. 10 TRACT 49 BEING THE MOST EASTERLY 80 ACRES, ORIGINALLY W2SE SEC. 3 T024N R114W SEC-0002 LOTS 16 (39.10), 17 (5.71), 18 (6.48) T024N R114W SEC-0003 LOTS 12 (22.51), 13 (20.35) LOTS 14 (17.84), 18 (17.84) 50037-00 ST WY 08945 09/16/1949 BK 5 PG 382 WY LINCOLN T025N R114W SEC-0036 SESE LOT 40, E2SWSE LOT 40 ALL LESS AND EXCEPT SESE LOT 40, E2SWSE LOT 40 50038-00 USA W-01902 03/01/1950 BK 10 PG 134 WY LINCOLN T024N R114W SEC-0003 W2 LOT 10 AND LOT 11, E2 LOT 10 50039-00 USA EV-024522-A 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 SESE 50040-00 USA EV-024521-A 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 SESE 50041-00 USA EV-024522 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0015 SENW, S2NE, SE, E2SW, N2N2, SWNW, E2SW T023N R112W SEC-0021 NE, N2SE, SWSE T023N R112W SEC-0028 NE 50042-00 USA EV-24521-B 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0022 N2, N2S2, S2SW, SWSE T023N R112W SEC-0023 NWNW, NE, NENW, S2NW, S2 T023N R112W SEC-0027 NW, N2NE 50059-00 CHAMPLIN PETROLEUM CO. 10/03/1973 BK108 PG 437 WY LINCOLN T022N R112W SEC-0021 E2SW, SE, SENW, S2NE 50065-00 USA W-0127851 10/01/1961 BK PG WY SUBLETTE T030N R113W SEC-0013 SWNE, SE 50066-00 USA W-02274 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NENW, S2NW T030N R113W SEC-0024 SE, NESW, E2NE, NWNE, E2NW 50067-00 USA W-02274-A 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0013 NWNW 50068-00 USA EV-024526-G 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENW 50069-00 USA W 16769 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 LOTS 1,2,3,4 50070-00 USA W-05504 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0014 E2NE, NESE 50071-00 USA EV-024538-A 12/01/1948 BK PG WY SUBLETTE T030N R113W SEC-0013 SW4 50075-00 USA EV-024354 11/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0034 ALL T029N R112W SEC-0033 E2NE, SE 50076-00 ANDERSON L MCGINNIS 06/01/1953 BK 86 PG 492 WY SUBLETTE T028N R112W SEC-0019 LOT 2, SENW 50077-00 WILLIAM J MCGINNIS 03/12/1963 BK 36 PG 119 WY SUBLETTE T028N R112W SEC-0017 S2N2, N2SW, NWSE, SWSW T028N R112W SEC-0018 SE, SESW, LOT 4 T028N R112W SEC-0019 NWNE 50078-00 USA EV-024355 09/01/1949 BK PG WY SUBLETTE T029N R112W SEC-0032 E2, E2W2 T029N R112W SEC-0033 W2, W2NE 50082-00 USA EV-024470 01/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0027 ALL T029N R112W SEC-0028 SWSE, S2SESE, E2SESW, W2SESW, N2SESE, NW, NE, N2S2, SWSW T029N R112W SEC-0029 W2SW, NE, NW, SE, E2SW 50084-00 USA W-53496 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0029 W2E2, SW, E2NW, SWNW, NWNW T028N R112W SEC-0030 SE, LOT 2 (33.12 ACS), LOT 3 (32.59 ACS), LOT 4 (32.24 ACS), NE, E2W2 T028N R112W SEC-0031 NE, LOT 1 (31.93 ACS), LOT 2 (31.68 ACS), LOT 3 (31.42 ACS), SE, E2W2 T028N R112W SEC-0032 W2NW 50085-00 USA W-53498 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 W2NE, NWSE, E2NW, E2NESW, SWSE, S2SW, W2NESW 50087-00 USA W 92216 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0005 LOTS 1-12 S2 T028N R112W SEC-0006 LOTS 1, 3-18, E2SW, SE T028N R112W SEC-0007 LOTS 1-4, E2, E2W2 50089-00 USA W 92219 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 N2NWSW, W2 LOT 4(19.19), LOT 5(40.0), LOT 12(40.0) E2 LOT 4, S2NWSW 50093-00 USA EV-022234 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0020 LOT 5 T028N R113W SEC-0029 NE/4; E/2 NW/4; NE/4 SW/4; N/2 SE/4; SE/4 SE/4 50097-00 USA EV-023584 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0023 LOT 4 (27.24), W2NW 50099-00 USA EV-024353 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 LOTS 6,7,8, E2SW, SWSE, TRACT 43-B 50103-00 USA W-0256492 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0021 LOT 7, TRACTS 43-A, 43-C T028N R113W SEC-0028 LOTS 2,3,4,9,10, TRACTS 50-B, 50-D, LOT 11 50107-00 USA W-0637 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0015 SE, SWNE, W2 50111-00 USA EV-022239 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0008 E2, E2W2 50112-00 RUTH A CHAMBERLAIN, ET VIR 01/17/1950 BK 2 PG 295 WY SUBLETTE T028N R113W SEC-0020 E2NE T028N R113W SEC-0021 W2NW 50118-00 WILLIAM J MCGINNIS, ET AL 07/30/1947 BK 2 PG 158 WY SUBLETTE T028N R113W SEC-0021 TRACT 42 50124-00 USA EV-022241 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0022 W2SW, SESW, N2, LOT 1, NESW, NWSE T028N R113W SEC-0027 S2SW 50125-00 MARY H MCGINNIS 07/01/1946 BK 2 PG 101 WY SUBLETTE T028N R113W SEC-0027 RESURVEY TRACT 48 50128-00 USA W-48908 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0017 LOTS 1,3,4,5,6, SWNE, NWSE T028N R113W SEC-0021 LOTS 1,2,3,4,5,6,8, S2NE, N2SE, SESE, TR 43-D T028N R113W SEC-0028 LOTS 1,5,6,7,8, TRS 50-A & 50-C, S2SE T028N R113W SEC-0031 LOTS 7,8 T028N R113W SEC-0032 TR 53 50130-00 USA EV-07538 01/01/1940 BK 89 PG 76 WY SUBLETTE T028N R113W SEC-0033 NWNW 50132-00 USA W-031454 03/01/1955 BK PG WY LINCOLN T026N R113W SEC-0009 E/2 50146-00 USA W-0256491 01/01/1940 BK PG WY SUBLETTE T028N R113W SEC-0033 NENW 50191-00 USA EV-024966-A 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 NWNW 50196-00 USA W-0125390 06/01/1955 BK PG WY SUBLETTE T029N R112W SEC-0030 LOTS 1, 2, 3, 4, E2W2, NWNE, S2NE, SE T029N R112W SEC-0031 E2W2, E2, LOTS 1, 2, 3, 4 50197-00 USA W-0125391 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOTS 5 (39.18 AC), 6 (38.97) 50199-00 USA W-0189 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 N2NE4 50200-00 USA W-014052 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 LOTS 7(40.43 ACS), 8(39.46) 50201-00 USA EV-026216 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2SW 50202-00 USA W-10680 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 7 50205-00 ST WY 0-10799 03/02/1951 BK PG WY SUBLETTE T029N R113W SEC-0001 NENE T030N R113W SEC-0036 ALL 50206-00 USA W 21125 05/01/1951 BK 84 PG 621 WY SUBLETTE T030N R113W SEC-0009 W2 T030N R113W SEC-0015 SWSW T030N R113W SEC-0021 N2 50207-00 USA W21123 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 W2NW 50208-00 USA W-04628 02/01/1956 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, S2SE, W2NE, NWSE 50210-00 ST WY 0-13662 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 E2SW, SE 50211-00 ST WY 0-11311 07/02/1951 BK PG WY SUBLETTE T030N R113W SEC-0016 S2NE 50212-00 ST WY 0-13663 04/07/1952 BK PG WY SUBLETTE T030N R113W SEC-0016 NW, W2SW 50220-00 USA W-04015-B 02/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2NENW, W2NENW 50223-00 USA EV-024526 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENWNE, NWNWNE, S2NWNE 50224-00 USA EV-026171 08/01/1950 BK PG WY SUBLETTE T030N R112W SEC-0018 SESW, LOTS 1,2,3,4, NWNE, S2NE, E2NW, NESW, SE T030N R112W SEC-0032 N2SW 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 NESW, SESW 50227-00 USA W-04101-B 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0029 E2SENW, W2SENW 50228-00 USA W-056555 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0008 NWNE, S2N2, LESS 6.37 AC INCL IN 67TH RESERVOIR T030N R112W SEC-0009 SW, W2SE, SESE T030N R112W SEC-0017 S2, S2N2 T030N R112W SEC-0020 W2W2, NENW T030N R112W SEC-0033 S2N2 50229-00 USA W-27641 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2, SENW 50230-00 USA W-055073 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0027 W2 T030N R112W SEC-0029 W2W2 T030N R112W SEC-0032 N2 T030N R112W SEC-0033 N2N2 T030N R112W SEC-0034 W2NW 50232-00 USA W-36567 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 N2NE, SWNE, NWSE 50233-00 USA W-027642 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 NENE, SENE 50235-00 ST WY 0-20914 08/16/1956 BK 16 PG 88 WY SUBLETTE T029N R112W SEC-0016 S2SW, NWSW, SWNW: LIMITED FROM SURFACE TO BASE OF MESAVERDE FORMATION (4,500'), SE, SWNE 50238-00 USA EV-024445-E 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 NE4NW4 50239-00 USA W-036663-A 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SESE 50240-00 USA EV-024445 09/01/1949 BK PG WY SUBLETTE T030N R112W SEC-0019 E2SW4 50241-00 USA W-036663 11/01/1955 BK 69 PG 1 WY SUBLETTE T029N R112W SEC-0017 SENE, NESE 50250-00 USA W-43911 08/01/1956 BK PG WY SUBLETTE T029N R112W SEC-0013 SE, S2SW T029N R112W SEC-0024 W2NW, SW T029N R112W SEC-0025 N2NW 50253-00 USA W-53499 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0022 SWNW, S2, S2NE T029N R112W SEC-0023 NE, NWSE, E2SE, NW, N2SW T029N R112W SEC-0026 NENE 50261-01 FIRST NAT'L BNK OF KEMMERER 12/29/72 BK 48 PG 628 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9, 11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2, 5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50261-02 DANIEL E CHAPEL 03/07/1981 BK 61 PG 461 WY SUBLETTE T028N R112W SEC-0024 SESW, LOTS 9,11 T028N R112W SEC-0025 SENW, N2NW, LOTS 2,5 T028N R112W SEC-0026 LOTS 1,7, AND ALL THAT PART OF THE GREEN RIVER RIPARIAN THERETO 50265-00 USA W-48517 01/01/1975 BK 68 PG 367 WY SUBLETTE T029N R112W SEC-0017 SENW, E2SW, SWSE 50330-00 ST WY #67-4099 04/02/1967 BK 42 PG 205 WY SUBLETTE T027N R112W SEC-0016 E2 BEING W2NE, SESE, LOTS 1-5, 7, PORTION LOT 6 IN SWSE (5.31 AC)-PORTION IN CONFINES GREEN RIVER BED 50332-00 USA W-05690 07/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0015 SWNW 50333-00 USA W-020778 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0035 E2, NW4 50335-00 USA W-05691 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0005 LOTS 5,6 50336-00 USA EV-021954 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0022 NWNE 50337-00 USA W-51101 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0003 S2S2 T027N R114W SEC-0004 S2 T027N R114W SEC-0005 LOTS 13,14,15,16, E2 LOT 23,24, W2 LOT 23 T027N R114W SEC-0009 NE, E2NW, N2SE, SESE T027N R114W SEC-0010 SWSW 50345-00 USA W-64986 09/13/1978 BK 74 PG 522 WY SUBLETTE T027N R112W SEC-0011 S2 T027N R112W SEC-0014 N/2 50356-00 USA W-0231770 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0025 NW4NW4 50357-00 USA W-0231771 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 W2SW4 50358-00 USA W-0231772 06/01/1952 BK 69 PG 549 WY SUBLETTE T028N R113W SEC-0002 SWNW, NWSW T028N R113W SEC-0003 NWSE, S2NE, NESE, LOTS 5 & 6 50359-00 USA W-024931-A 10/01/1948 BK PG WY SUBLETTE T029N R113W SEC-0025 SENW, SWNW 50360-00 USA EV-025930 08/01/1949 BK PG WY SUBLETTE T029N R113W SEC-0023 E2W2 50361-00 USA W-031992 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0026 N2NE4, NE4NW4 50363-00 USA W-014051 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 LOT 8 50364-00 USA W-02683 10/01/1950 BK 31 PG 213 WY SUBLETTE T029N R113W SEC-0025 E2SW, SWSE 50366-00 USA EV-021767 09/01/1950 BK 89 PG 10 WY SUBLETTE T029N R113W SEC-0035 SE4 50374-00 USA W-62801 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0007 LOTS 1 THRU 4, E2, E2W2 T031N R113W SEC-0018 LOTS 1 THRU 4, E2, E2W2 50380-00 USA W-60577 11/01/1977 BK 88 PG 764 WY SUBLETTE T028N R111W SEC-0029 W2 T028N R111W SEC-0030 LOTS 1,2,3,4, E2, E2W2 T028N R111W SEC-0031 NE, E2SE T028N R111W SEC-0032 W2 50422-00 USA W-11603 04/01/1968 BK PG WY SUBLETTE T028N R114W SEC-0021 NE, SE 50424-00 ST WY 66-5165 03/02/1966 BK PG WY SUBLETTE T028N R114W SEC-0016 NENE, NW, N2SW, SE, SENE, S2SW, W2NE 50425-00 USA W-2120 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0015 NW, SW T028N R114W SEC-0022 SW 50427-00 USA W-055275 02/01/1959 BK PG WY SUBLETTE T026N R112W SEC-0022 NW, N2SW, S2SW 50428-00 BETTE M THOMPSON 07/06/1976 BK 53 PG 154 WY SUBLETTE T029N R113W SEC-0004 W2SW, SESW T029N R113W SEC-0005 E2SE T029N R113W SEC-0007 NESE, E2NE T029N R113W SEC-0008 N2NE, W2NW, NWSW, NESW, SE SENE, SENW, S2SW T029N R113W SEC-0009 N2NW, S2NW, W2SW T029N R113W SEC-0017 E2NW, NWNE 50439-00 USA W-73977 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0017 NWNW, E2, E2NW, NESW T032N R114W SEC-0020 NE, N2SE 50507-00 USA W-67176 08/01/1979 BK223 PG 400 WY LINCOLN T026N R111W SEC-0006 SENW, SWNE, W2SE, LOTS 3,4,5,6,7 T026N R111W SEC-0007 W2E2 57047-00 USA W-01763 09/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0002 SWNW TO29N R113W SEC-0003 NESE 57132-00 MONTE NORRIS 03/12/1985 BK 74 PG 285 WY SUBLETTE T031N R113W SEC-0019 E2SW, S2SE, LOTS 2, 4 T031N R113W SEC-0030 NENW, N2NE T031N R114W SEC-0023 SENE T031N R114W SEC-0024 NW, N2SE, SESE, S2NE 58005-00 USA WYW-116385 07/01/1978 BK PG WY SUBLETTE T031N R113W SEC-0019 LOTS 1,3, N/2NE, E/2NW T031N R113W SEC-0030 LOTS 1,2,3,4, E/2SW 58343-00 USA W-34033 05/01/1972 BK 57 PG 280 WY SUBLETTE T027N R111W SEC-0029 NENE 58344-00 USA W-35398 07/01/1972 BK 63 PG 605 WY SUBLETTE T027N R111W SEC-0008 SWSE T027N R111W SEC-0017 NE 58345-00 USA W-35399 07/01/1972 BK 64 PG 633 WY SUBLETTE T027N R111W SEC-0015 N2 58346-00 USA W-36422 10/01/1972 BK 57 PG 359 WY SUBLETTE T027N R111W SEC-0022 N2 T027N R111W SEC-0023 ALL T027N R111W SEC-0025 SE, W2 T027N R111W SEC-0026 ALL 58347-00 USA W-51347 08/01/1975 BK 61 PG 447 WY SUBLETTE T027N R111W SEC-0005 NW,SW T027N R111W SEC-0006 SE, S2NE T027N R111W SEC-0007 NE T027N R111W SEC-0008 NW, N2SW 58348-00 USA W-54136 04/01/1976 BK 64 PG 638 WY SUBLETTE T027N R111W SEC-0014 ALL T027N R111W SEC-0015 S2 58349-00 USA W-54137 04/01/1976 BK 64 PG 155 WY SUBLETTE T027N R111W SEC-0017 SE T027N R111W SEC-0020 NE 58350-00 USA W-58724 05/01/1977 BK 54 PG 470 WY SUBLETTE T027N R111W SEC-0019 LOTS 1-4, E2W2, W2SE, SWNE T027N R111W SEC-0030 LOTS 1-3, E2W2, E2 58351-00 USA W-59776 09/01/1977 BK 64 PG 278 WY SUBLETTE T027N R111W SEC-0020 NESW 58352-00 USA W-62117 02/01/1978 BK 60 PG 198 WY SUBLETTE T027N R111W SEC-0028 NW, N2SW, SESW 58353-00 USA W-62508 11/01/1978 BK 57 PG 187 WY SUBLETTE T027N R111W SEC-0029 SE, SENE, W2, W2NE 58354-00 USA W-62875 04/01/1978 BK 68 PG 533 WY SUBLETTE T027N R111W SEC-0030 LOT 4 58355-00 USA W-63490 06/01/1978 BK 66 PG 168 WY SUBLETTE T027N R111W SEC-0032 NW, N2SW, LOT 2 58356-00 USA W-63821 07/01/1978 BK 57 PG 195 WY SUBLETTE T027N R111W SEC-0032 LOTS 3 AND 4, N2SE, NE 58357-00 USA W-67808 06/01/1979 BK PG WY SUBLETTE T027N R111W SEC-0006 N2NE T027N R111W SEC-0007 SE T027N R111W SEC-0018 E2NE, E2SE T027N R111W SEC-0019 E2NE, E2SE 58358-00 USA W-68116 07/01/1979 BK708 PG1493 WY SWEETWATER T026N R111W SEC-0004 SW, LOTS 1-4, S2N2, SE T026N R111W SEC-0010 S2N2 58359-00 USA W-68117 07/01/1979 BK 59 PG 7 WY SUBLETTE T027N R111W SEC-0008 S2SW T027N R111W SEC-0017 W2 T027N R111W SEC-0020 NW, NWSW, SE, S2SW 58360-00 USA W-68454 09/01/1979 BK 71 PG 306 WY SUBLETTE T027N R111W SEC-0028 SWSW 58960-00 USA WYW-034924 04/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0023 SWNE 58961-00 USA WYW-034927 05/01/1948 BK PG WY SUBLETTE T027N R114W SEC-0001 W2SW 58962-00 USA WYW-034930 10/01/1950 BK 86 PG 232 WY SUBLETTE T027N R114W SEC-0022 NENE T027N R114W SEC-0023 NW, NWNE 58963-00 STATE OF WYOMING #0-20476 01/16/1956 BK150 PG 285 WY SUBLETTE T028N R114W SEC-0036 N2, N2S2, S2SW 59023-00 USA EV-026053 10/01/1949 BK 86 PG 283 WY SUBLETTE T029N R113W SEC-0035 NE 59041-00 STATE OF WYOMING #0-11193 05/16/1951 BK 3 PG 350 WY SUBLETTE T029N R113W SEC-0036 ALL 75114-00 USA WY-0311662 10/01/1964 BK 38 PG 373 WY SUBLETTE T028N R114W SEC-0005 LOTS 9, 10, 14, 15, 16, 17, 18, 19 T028N R114W SEC-0008 LOTS 2, 3, 4, 5, 6, 7, 8, 9, 10 11,12,13,14,15,16,17,18,19,20 T028N R114W SEC-0021 SESW, W2SW 75116-00 USA WY-51104 04/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0017 LOT 4 T208N R115W SEC-0012 NW 75117-00 USA WY-42791 01/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0005 LOTS, 7, 8, 12 T028N R114W SEC-0021 NESW, N2NW, SENW 75118-00 USA WY-51103 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0017 LOTS 1,2,3,5,6,7,8,9,10,11, 12,13,14,15,16,17,18,19,AND 20 75119-00 USA WY-320213 11/01/1965 BK PG WY SUBLETTE T028N R114W SEC-0020 LOTS, 1,2,3,4,5,6,7,8,9 10 11,12,13,14,15,16,17,18,19,AND 20 75120-00 USA WY-52811 12/01/1975 BK PG WY SUBLETTE T028N R114W SEC-0022 NW 75123-00 USA WY-38076 02/01/1973 BK PG WY SUBLETTE T028N R114W SEC-0009 W2SE, E2SE, N2SW T028N R114W SEC-0010 SW 75124-00 USA WY-9578 12/01/1967 BK PG WY SUBLETTE T208N R114W SEC-0003 LOTS 7 THRU 10 LOTS 15 THRU 18 T028N R114W SEC-0004 LOTS 5 THRU 20 T028N R114W SEC-0005 NWSE, S2NE, LOTS 5, 6, 13, 20 T028N R114W SEC-0009 N2 T028N R114W SEC-0010 NW 50006-00 USA W-125389 09/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0019 LOTS 3(12.53) 4(12.13). E/2SW SWSE LOT 2(12.63). NENE,S2NE, N2SE, SESE, SENW 50007-00 USA W-0231774 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0002 S2NE, N2SE, S2SE 50009-00 USA W-0231773 06/01/1952 BK PG WY SUBLETTE T028N R113W SEC-0001 S2NW, N2SW, S2SW 50010-00 USA EV-022755 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0011 W2 50014-00 USA W-10674 12/31/1938 BK 88 PG 775 WY SUBLETTE T029N R113W SEC-0014 SENE, E2SE T029N R113W SEC-0015 S2N2, S2 50016-00 USA W-085597 (ROW) 01/01/1958 BK PG WY SUBLETTE T027N R113W SEC-0018 SENW (ROW) 50017-00 USA EV-024756-A 06/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0024 LOT 2 50024-00 USA W-20039 03/01/1969 BK PG WY SUBLETTE T028N R114W SEC-0033 SWNE 50026-00 USA W-054585 07/01/1951 BK PG WY SUBLETTE T027N R113W SEC-0012 NENW, SWSW 50043-00 USA W-71775 11/01/1948 BK PG WY LINCOLN T023N R112W SEC-0027 NESW, SE, SESW, S2NE, W2SW 50044-00 USA W-71776 11/01/1948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0028 NESW, NW, SE, SESW 50045-00 USA W-92975 11/011948 BK 32 PG 228 WY LINCOLN T023N R112W SEC-0021 W2 T023N R112W SEC-0028 W2SW 50055-00 USA EV-025548 01/01/1948 BK PG WY SUBLETTE T027N R112W SEC-0026 ALL T027N R112W SEC-0027 E2 50056-00 USA W-05923 06/01/1951 BK PG WY SUBLETTE T022N R112W SEC-0009 S2 50057-00 USA W-45370 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0020 E2SW, SE, SENW, S2NE T022N R112W SEC-0021 NWSW, SWNW 50058-00 USA W-45371 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0028 NWNW 50060-00 USA W-0319563 10/01/1965 BK PG WY LINCOLN T022N R112W SEC-0034 NW 50061-00 USA W-05924 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0015 N2S2, SWSW T022N R112W SEC-0022 N2, S2, T022N R112W SEC-0026 NE 50062-00 USA W-05925 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0026 N2SE, SWSE, W2 T022N R112W SEC-0028 E2, E2W2, SWNW, W2SW 50063-00 USA W-71772 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0010 SE, E2SW, NWSW, SWSW T022N R112W SEC-0020 W2W2, NENW, N2NE T022N R112W SEC-0021 N2N2 50064-00 USA W-71773 06/01/1951 BK PG WY LINCOLN T022N R112W SEC-0029 NWNW 50072-00 USA EV-024528 01/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0028 SENE, W2NE, W2, SE T028N R112W SEC-0029 E2E2 50073-00 USA W-035077 12/01/1955 BK PG WY SUBLETTE T028N R112W SEC-0032 E2E2 50074-00 USA EV-024469 12/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0017 N2NE, E2SE, SWSE T028N R112W SEC-0020 E2NE, W2NE, SE T028N R112W SEC-0021 ALL 50079-00 USA EV-024735 01/01/1949 BK PG WY SUBLETTE T028N R112W SEC-0006 W2 LOT 2 E2 LOT 2 50080-00 USA EV-026175 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0004 LOTS 1,2,3,6,7,8,9,10,11,SE,E2SW,SWSW 50081-00 USA EV-023340 07/01/1948 BK PG WY SUBLETTE T028N R112W SEC-0008 NW, W2SW 50086-00 USA W-53497 08/01/1950 BK PG WY SUBLETTE T028N R112W SEC-0008 E2, E2SW T028N R112W SEC-0009 N2, S2 50092-00 USA EV-020363 07/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0032 LOTS 2,5 50095-00 USA EV-022281 07/01/1948 BK 32 PG 690 WY SUBLETTE T028N R113W SEC-0027 LOTS 1,4,5,7,8 50096-00 USA EV-022285 10/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0009 ALL 50098-00 USA EV-023969 07/01/1948 BK 32 PG 37 WY SUBLETTE T028N R113W SEC-0008 W2W2 T028N R113W SEC-0027 LOTS 2,3, T028N R113W SEC-0029 W2NW 50100-00 USA EV-025535 08/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0010 W2 50104-00 USA EV-025992 03/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0027 SWNW 50105-00 USA WY 0516 05/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0033 E2 50106-00 USA W-0636 04/01/1950 BK PG WY SUBLETTE T028N R113W SEC-0005 SW, SWNW 50108-00 USA CH-082277 06/01/1950 BK PG WY SUBLETTE T029N R113W SEC-0028 S2NE4, SE4 50109-00 ST WY 0-7395 09/16/1948 BK PG WY SUBLETTE T029N R113W SEC-0016 E2, NW, SW 50110-00 WILLIAM J. MCGINNIS ET AL 07/30/1947 BK 2 PG 162 WY SUBLETTE T028N R113W SEC-0017 TRACT 38 (AKA NESW) TRACT 40 (AKA SWSE) 50114-00 ST WY #0-04732 09/16/1944 BK 36 PG 155 WY SUBLETTE T028N R113W SEC-0016 ALL (RESURVEY TRACT 37) 50115-00 USA W-04732 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0004 LOTS 7,8, S2NW, SW 50116-00 USA W-026038-A 02/01/1950 BK 31 PG 206 WY SUBLETTE T029N R113W SEC-0021 E2 T029N R113W SEC-0027 NWNW T029N R113W SEC-0028 N2NE 50117-00 USA W-0195876 02/01/1962 BK PG WY SUBLETTE T029N R114W SEC-0025 E2NE 50119-00 USA W-04731 02/01/1951 BK PG WY SUBLETTE T028N R113W SEC-0005 LOTS 5,6,7,8, S2NE, SE, SENW 50120-00 ANDERSON L. MCGINNIS ET UX 07/30/1947 BK 2 PG 156 WY SUBLETTE T028N R113W SEC-0027 PT OF TRACT 49 (W2NW, SENW) T028N R113W SEC-0028 PT OF TRACT 49 (NENE) 50121-00 MARY J. HADDENHAM 07/30/1947 BK PG WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW, (RESURVEYED AND DESCRIBED AS TRACT 39) 50122-00 MARY J. (B) HADDENHAM 07/30/1947 BK 2 PG 153 WY SUBLETTE T028N R113W SEC-0017 W2SW, SESW (RESURVEYED AND DESCRIBED AS TRACT 39) 50123-00 USA EV-025771 01/01/1948 BK 32 PG 55 WY SUBLETTE T028N R113W SEC-0022 LOT 2 T028N R113W SEC-0026 LOT 2, SWNW, W2SW 50126-00 USA W-48905 10/01/1948 BK PG WY SUBLETTE T028N R113W SEC-0016 LOTS 1 THRU 7 T028N R113W SEC-0017 NWNE T028N R113W SEC-0020 LOTS 2,3,4, S2NW T028N R113W SEC-0029 SWSE, SESW 50127-00 USA W-48906 11/01/1946 BK PG WY SUBLETTE T028N R113W SEC-0020 NWSW 50129-00 USA W-70864 10/17/1980 BK PG WY SUBLETTE T028N R113W SEC-0028 SENE-50 FT R-O-W 50148-00 USA EV-09561-B 04/23/1935 BK PG WY SUBLETTE T027N R113W SEC-0017 W2NW 50189-00 USA W-0136175 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0026 SW T030N R113W SEC-0027 E2NE, W2NE 50190-00 USA W-0136177 04/01/1951 BK 47 PG 103 WY SUBLETTE T030N R113W SEC-0022 SE 50192-00 USA W-27645 04/01/1951 BK 47 PG 103 wy SUBLETTE T030N R113W SEC-0010 W2SE, SW, NWNW, E2SE, NE, NENW, S2NW T030N R113W SEC-0014 S2SW, SWSE, N2SW, NWSE, SESE, W2NE, NW T030N R113W SEC-0022 NE, E2NW 50193-00 USA W-27644 08/01/1950 BK PG WY SUBLETTE T030N R1113W SEC-0011 NE, SE T030N R1113W SEC-0024 W2NW, NWSW, S2SW 50194-00 USA EV-024966 08/01/1949 BK PG WY SUBLETTE T030N R113W SEC-0023 E2NE, E2NW, E2SE, SW, SWNW, W2NE, W2SE 50203-00 USA W-0231769 06/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0032 W2NW4 50204-00 USA EVANSTON 024241 05/01/1948 BK 18 PG 92 WY SUBLETTE T028N R113W SEC-0001 LOTS, 5,6, 9, 10, 11, SWNE, W2SE T028N R113W SEC-0012 LOTS 1-4, W2E2, W2 T028N R113W SEC-0013 LOTS 1-3, W2E2, NW 50208-00 USA W-04628 02/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0008 E2SE, NE, NW, W2SE T030N R113W SEC-0017 E2NE, NESE, NWSE, S2SE, W2NE -53- 50209-00 USA W-27643 12/01/1948 BK PG WY SUBLETTE T030N R112W SEC-0030 SENW, E2SW 50217-00 USA W-16770 12/10/1948 BJ PG WY SUBLETTE T029N R112W SEC-0006 LOT 5, SENW, S2NE, NWSE T030N R112W SEC-0030 SWNE, LOTS 1-4, SE T030N R112W SEC-0031 LOTS 3, 4, E2SW, N2SE, SESW, SESE LOTS 1, 2, E2NW, NE 50219-00 USA W-053447 02/01/1950 BK PG WY SUBLETTE T029N R112W SEC-0023 S2SW, SWSE 50225-00 USA W-039908 08/01/1956 BK PG WY SUBLETTE T029N R112 SEC-0024 E/2NW, E/2 T029N R112 SEC-0025 S/2, S/2N/2, N/2SE T029N R112 SEC-0035 ALL 50226-00 USA W-04101 03/01/1951 BK PG WY SUBLETTE T030N R112W SEC-0020 E2NE T030N R112W SEC-0029 NESW, SESW 50259-00 YOSE CATTLE COMPANY 12/17/1981 BK 64 PG 76 WY SUBLETTE T027N R112W SEC-0003 LOTS 2(34.31 ACS); 3(39.72 ACS); 4(39.71 ACS) 5(45.51 ACS); EXCEPTING FRACTIONAL PARTS OF LOTS 3, 4, & 5, MORE FULLY DESCRIBED IN LEASE T028N R112W SEC-0026 S/2 SW T028N R112W SEC-0034 W/2,W/2; NENW; E/2 SW; W/2 SE; SENE; NESE LOT 1 (23.57 ACS) T028N R112W SEC-0035 LOT 4(41.92 ACS); W/2 NW; NWSE LOT8 (35.13 ACS) 50263-00 USA W-077883 07/01/1976 BK PG WY SUBLETTE T028N R111W SEC-0019 LOTS 2,3,4,E2,E2NENW, SWNENW,E2SW T028N R111W SEC-0020 E2 T028N R111W SEC-0029 SE, NE T028N R111W SEC-0032 NE, SE 50266-00 USA W-87038 09/01/1984 BK PG WY SUBLETTE T029N R112W SEC-0011 SWSW 50289-01 A L MAHAFFEY 12/26/1956 BK20PR PG 282 WY LINCOLN T026N R112W SEC-0006 PART OF SEC 6 & 7 T026N R112W SEC-007 PART OF SEC 6 & 7 50289-02 BABE PROBASCO ET UX 12/27/1956 BK 21 PG 31 WY LINCOLN T026N R112W SEC-0006 BEGIN 148' N SWSE S6 THEN E 610',THEN S 148' THE E ON SEC LINE BTWN S6&7 FOR 433';THEN N 835';THEN W 1043.5';THEN S 687'TO POINT OF BEGINNING 50131-01 HOWARD A. MAHAFFEY 12/26/1956 BK 20 PG 278 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION 50314-00 GUY DECKER ET UX 03/17/1957 BK 32 PG 377 WY LINCOLN T026N R112W SEC-0006 LOT 11 OF LOT 8,LOT 1 OF BLOCK 1 OF SECOND ADDITION TO TOWN OF LABARGE 50137-00 LINCOLN COUNTY #1 05/08/1957 BK 22PR PG 166 WY LINCOLN T000N R000W SEC-0000 LARGE TOWNLOTS;ORIG TOWNSITE;TULSA-BK9 LOTS 4-7;1ST ADD;TULSA-BK 12, LOTS 13-15 RIVERVIEW ADD-TULSA - BK A,LT15,-BK B, L1-4,-BK C, L13, 20, 35 - BK E, L15, 16, 19,& 20 50326-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 172 WY LINCOLN T000N R000W SEC-0000 STREETS & ALLEYS IN LABARGE,WY ORIG PLATTED TULSA, WY SHOWN ON LINCOLN M/B MAP #1&2 SEE LST FOR LST OF STREETS & ALLEYS 50328-00 LINCOLN COUNTY, WYOMING 05/08/1957 BK 22 PG 176 WY LINCOLN T026N R112W SEC-0006 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0007 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0018 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0019 SEE LEASE FOR METES AND BOUNDS DESCRIPTION T026N R112W SEC-0020 SEE LEASE FORE METES AND BOUNDS DESCRIPTION 50334-00 USA W-8140 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0002 LOTS 1,2,3,4, S2N2, S2 (ALL) T027N R114W SEC-0003 LOTS 1,2,3,4, S2N2, N2S2 T027N R114W SEC-0004 LOTS 1,2,3,4, S2N2 T028N R114W SEC-0034 S2NE, SENW, S2 T028N R114W SEC-0035 SW 50338-00 USA W-72405 06/01/1951 BK PG WY SUBLETTE T027N R114W SEC-0009 W2NW 50339-00 USA W-92223 07/01/1951 BK 65 PG 466 WY SUBLETTE T027N T114W SEC-0010 S2NE, NW, E2SW, NWSW, SW, N2NE T027N R114W SEC-0011 W2SW, N2, SE, E2SW T027N R114W SEC-0012 W2NW, NWNSW T027N R114W SEC-0014 SWNE, NW, S2, N2NE, SENE T027N R114W SEC-0015 NE, E2NW, NWNW 50340-00 USA W092222 10/01/1947 BK PG WY SUBLETTE T027N R114W SEC-0015 NESW, SE 50341-00 USA W-96755 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0027 SE4 50342-00 USA W-96756 06/01/1951 BK PG WY SUBLETTE T028N R114W SEC-0033 SE T028N R114W SEC-0034 N2N2, SWNW 50382-00 USA W-42781 01/01/1974 BK PG WY SUBLETTE T027N R111W SEC-0004 N2 T027N R111W SEC-0005 E2 T027N R111W SEC-0008 NE, N2SE. SESE T027N R111W SEC-0009 E2, W2 50421-00 USA W-20038 03/01/1969 BK PG WY SUBLETTE T027N R1114W SEC-0028 E/2NE4, NW/NE, NW/SE 50423-00 USA W-054586 06/01/1953 BK PG WY SUBLETTE T028N R114W SEC-0015 NE, E2SE T028N R114W SEC-0022 E2NE, SE T028N R114W SEC-0027 W2NE, SENE 50426-00 USA W-2121 11/01/1966 BK PG WY SUBLETTE T028N R114W SEC-0028 SWNE 50433-000 THEODORE JORDAN, ET AL 08/19/1954 BK 10 PG 170 WY SUBLETTE T029N R113W SEC-0004 S2SE4 T029N R113W SEC-0009 NE T029N R113W SEC-0010 N2NW, SENW 50437-00 USA W-19959 08/01/1969 BK 2 PG WY SUBLETTE T032N R114W SEC-0008 S2NW, N2SW LOTS 3, 4, S2SW 50438-00 USA W-06009 06/01/1951 BK 2 PG 506 WY SUBLETTE T032N R114W SEC-0007 LOTS 1 (10.71) 2, (10.05) S2NE 50454-00 USA W-0320844 12/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0033 NWNW 50505-00 USA W-38503 03/01/1973 BK103 PG 402 WY LINCOLN T026N R111W SEC-0005 LOTS 1 & 2, S2NE, SE T026N R111W SEC-0008 E2 50506-00 USA W-57837 03/01/1973 BK552 PG 318 WY SWEETWATER T026N R111W SEC-0009 ALL 56833-00 USA W-85884 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0030 SENW 56931-00 USA W-107069 01/01/1988 BK 80 PG 747 WY SUBLETTE T031N R114W SEC-0013 N2, N2SW, SESW, SE T031N R114W SEC-0014 NW T031N R114W SEC-0023 NESW, S2SW T031N R114W SEC-0024 SW T031N R114W SEC-0025 W2E2, NW, SESE 57396-00 USA WYW-112556 08/01/1988 BK PG WY SUBLETTE T029N R112W SEC-0009 SESW, SWSE T029N R112W SEC-0010 S/2S/2 T029N R112W SEC-0015 ALL 57427-00 USA W-113137 10/01/1988 BK 81 PG 756 WY SUBLETTE T032N R114W SEC-0025 E/2, SENW, SW 57543-00 USA W-113659 12/01/1988 BK 89PR PG 89 WY LINCOLN T026N R113W SEC-0032 S/2NE, NW, N/2SW, SWSW, SE T026N R113W SEC-0033 SWNW, S/2 57544-00 USA W-113654 12/01/1988 BK267PR PG 383 WY LINCOLN T025N R113W SEC-0017 ALL T025N R113W SEC-0020 ALL T025N R113W SEC-0021 ALL 57545-00 USA W-113651 12/01/1988 BK267 PG 391 WY LINCOLN T025N R113W SEC-0004 NENE T025N R113W SEC-0005 E2, N2NW T025N R113W SEC-0006 LOTS 1, 6, 10, E2 T025N R113W SEC-0007 LOTS 3, 4, 6, THRU 12, NENE, SE, S2NE T025N R113W SEC-0008 NE, N2SE, SW, SWSE, S2NW T025N R113W SEC-0009 NESW, S2SW, W2NW 57546-00 USA WYW-113644 12/01/1988 BK 82 PG 153 WY SUBLETTE T028N R112W SEC-0032 NWSW 57547-00 USA WYW-113645 12/01/1988 BK 82 PG 165 WY SUBLETTE T029N R112W SEC-0017 NENW, SWNW, W/2SW T029N R112W SEC-0020 NENW T029N R112W SEC-0026 W/2NE, SENE, W/2, SE T029N R112W SEC-0030 NENE 57548-00 USA W-113661 12/01/1988 BK 82 PG 250 WY SUBLETTE T029N R113W SEC-0001 LOT 2, SWNE T029N R113W SEC-0006 LOTS 1 THRU 4 T029N R113W SEC-0007 LOT 3, 4, E/2SW, W/2SE, SESE 57641-00 USA WYW-114579 02/01/1989 BK 82 PG 446 WY SUBLETTE T027N R112W SEC-002 THAT PORTION OF GREEN RIVER RIPARIAN TO LOT 5, BEING MORE PARTICULARLY DESCRIBED ON LEASE 57824-00 USA WY-115956 06/01/1989 BK 83 PG 364 WY SUBLETTE T028N R112W SEC-0010 S/2NE, SE T028N R112W SEC-0011 SWNW, NWSW 57825-00 USA WYW-115961 06/01/1989 BK 83 PG 373 WY SUBLETTE T030N R113W SEC-0007 E/2SE T030N R113W SEC-0008 NWSW T030N R113W SEC-0018 NENE 57826-00 USA WYW-115960 06/01/1989 BK 83 PG 379 WY SUBLETTE T028N R113W SEC-0013 LOT 4 T028N R113W SEC-0024 LOT 1 57952-01 DUANE HARWARD ET UX TRUST 04/21/1989 BK275PR PG 142 WY LINCOLN T026M R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF THE REGISTER OF DEEDS, LINCOLN COUNTY, WY. 57952-02 DIAMOND H RANCH, INC. 02/28/1989 BK275PR PG 488 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS HIGHWAY TRACT, MORE FULLY DESCRIBED IN BOOK 21 PAGE 143 AND LESS THE EUBANK FOOTHILL ESTATES,MORE FULLY DESCRIBED AT PLAT #314 OF THE OFFICE OF THE REGISTER OF DEEDS, LINCOLN CO., WY. 57952-03 WILLIAM B SPENCER ET UX 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-04 MARY H LAMBERT ET AL 04/21/1989 BK275PR PG 140 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO.,WY 57952-05 ISABEL H SPENCER TRUST 04/21/1989 BK275PR PG 148 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY. 57952-06 WILLIAM B SPENCER TRUST 04/21/1989 BK275PR PG 146 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-07 JEAN S STEPHENS 04/21/1989 BK275PR PG 150 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN, CO., WY 57952-08 GLENISLA HUNTER ET AL 04/21/1989 BK275PR PG 152 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT, MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-09 LOIS S BRADY 04/21/1989 BK275PR PG154 WY LINCOLN T026N R112W SEC-0019 S/2SE, SESW, LESS A HIGHWAY TRACT,MORE FULLY DESCRIBED IN BOOK 21 AT PAGE 143 OF OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 57952-10 EUBANK CATTLE COMPANY 05/30/1989 BK276PR PG 303 WY LINCOLN T026N R112W SEC-0019 TRACT OF LAND IN SESW, S/2SE, KNOWN AS THE EUBANK FOOTHILL ESTATE, RECORDED AT PLAT #314 IN OFFICE OF REGISTER OF DEEDS, LINCOLN CO., WY 58055-05 MILLER ROBERT M JR ET UX 06/22/1989 BK 83 PG 679 WY SUBLETTE T029N R112W SEC-0004 W/2SW T029N R112W SEC-0005 E/2SE, SWSE T029N R112W SEC-0008 E/2 T029N R112W SEC-0009 W/2W/2 58188-00 USA WYW-117869 11/01/1989 BK 85 PG 426 WY SUBLETTE T027N R112W SEC-0002 BED OF GREEN RIVER RIPARIAN TO LOTS 6 - 8 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0003 BED OF GREEN RIVER RIPARIAN TO LOTS 1, 6, 7, 10, 11 ***SEE LEASE FOR COMPLETE DESCRIPTION*** T027N R112W SEC-0034 BED OF GREEN RIVER RIPARIAN TO LOT 2 ***SEE LEASE FOR COMPLETE DESCRIPTION*** 58189-00 USA W-117878 11/01/1989 BK 84 PG 606 WY SUBLETTE T031N R114W SEC-0009 S/2 T031 R114W SEC-0010 N/2 T031N R114W SEC-0014 N/2SW 58190-00 USA WYW-117867 11/01/1989 BK 85 PG 419 WY SUBLETTE T028N R111W SEC-0003 SW T018N R111W SEC-0002 ALL T028N R111W SEC-0027 ALL 58193-00 STATE OF WY-8900650 10/02/1989 BK 84 PG 614 WY SUBLETTE T031N R114W SEC-0016 W/2 58419-00 STATE OF WYOMING #89-00780 12/02/1989 BK 85 PG 389 WY SUBLETTE T030N R112W SEC-0016 ALL 58420-00 STATE OF WYOMING #89-00781 12/02/1989 BK 85 PG 39 WY SUBLETTE T030N R112W SEC-0028 S/2NE 58421-00 STATE OF WYOMING #89-00782 12/02/1989 BK 85 PG 393 WY SUBLETTE T030N R112W SEC-0032 NESE, SWSE 58423-00 USA WY-95121 11/01/1985 BK 84 PG 623 WY SUBLETTE T030N R112W SEC-0007 LOTS 2, 3, 4,, W/2NE, SENE, E/2SW, (LESS 6 ACRES) T030N R112W SEC-0027 SWSE T030N R112W SEC-0032 NWSE 58424-00 USA WYW-118696 01/01/1990 BK 85 PG 382 WY SUBLETTE T031N R114W SEC-0005 LOT 4(41.15), SWNW, NWSW, S/2S/2 T031N R114W SEC-0008 NE, S/2 T031N R114W SEC-0017 ALL T031N R114W SEC-0020 ALL 58521-00 GORDON W BRAY, ET UX 11/10/1989 BK 84 PG 653 WY SUBLETTE T030N R112W SEC-0026 W/2SW, SWNW T030N R112W SEC-0027 S/2NE, N/2SE, SESE T030N R112W SEC-0034 N/2NE, E/2NW 58551-00 USA W-106177 11/01/1987 BK PG WY SUBLETTE T030N R112W SEC-0015 NWNW T030N R112W SEC-0017 N/2NW (LESS 1.37 ACRES, MORE OR LESS IN T030N R112W SEC-0020 W/2E/2, SENW, NESW 58561-01 HELEN JENKINS O'NEIL 12/12/1989 BK 85 PG 91 WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58561-02 MIRIAM JENKINS BAILEY 12/11/1989 BK 85 PG 87 WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW,S/2 58561-03 JOHN PERRY BARLOW, ET UX 12/11/1989 BK 85 PG WY SUBLETTE T030N R112W SEC-0020 E/2SE T030N R112W SEC-0021 NWNE, S/2NE, W/2, SE T030N R112W SEC-0022 NWSW T030N R112W SEC-0028 N/2N/2, S/2NW, S/2 58562-00 BRUCE E JONES ET UX 11/13/1989 BK281PR PG 592 WY LINCOLN T025N R113W SEC-0006 LOTS 3(17.85),4(17.00),5(40.00),7(40.00), 11(40.00) 59157-01 PAUL HOMER, ET UX 05/22/1990 BK 86 PG 559 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-02 WILLIAM CHARLES CHRISTY 05/23/1990 BK 86 PG 571 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-03 KIMBERLY S CHRISTY, ET UX 05/22/1990 BK 86 PG 567 WY SUBLETTE T030N R112W SEC-0032 S/2, SW/4 59157-04 CATHLEEN E CHRISTY THOMAS 05/22/1990 BK 86 PG 563 WY SUBLETTE T030 R112W SEC-0032 S/2, SW/4 59162-00 USA WYW-112560 07/01/1988 BK PG WY SUBLETTE T030N R112W SEC-0013 N/2, NE/4 AND SE/4, NE/4 T030N R112W SEC-0025 ALL T030N R112W SEC-0026 N/2 AND SE/4 T030N R112W SEC-0035 W/2 59195-00 USA WYW-121426 10/01/1990 BK 86 PG 718 WY SUBLETTE T031N R114W SEC-0012 E2 75002-00 USA WY-107066 01/01/1988 BK PG WY SUBLETTE T024N R114W SEC-0004 LOT 13 T024N R114W SEC-0008 NE, SW T024N R114W SEC-0017 N2, SW T024N R114W SEC-0020 N2, N2S2, S2SW 75004-00 USA WYW-122224 11/01/1990 BK PG WY LINCOLN T025N R112W SEC-0027 NENE, LOTS 1,2,6 75025-01 ELIZABETH D BENNETT 06/01/1990 BK291PR PG 311 WY LINCOLN T025N R112W SEC-0005 LOT 9(1.50), 13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-02 DORISE E HOUSLEY 10/24/1990 BK291PR PG 455 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-03 DENESE STACY 10/24/1990 BK291PR PG 398 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03), NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-04 ALVIN MARX, ET UX 10/24/1990 BK291PR PG 638 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-05 ERWIN MARX, ET UX 10/24/1990 BK291PR PG 453 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-06 DOROTHY J MCGINNIS ET VIR 10/24/1990 BK291PR PG 396 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75025-07 ELDON E MARX, ET UX 10/24/1990 BK291PR PG 394 WY LINCOLN T025N R112W SEC-0005 LOTS 9(21.50),13(43.03),NWSE AND THE RIPARIAN RIGHTS TO LOTS 9 & 13 T025N R112W SEC-0008 NENW, LOT 1 75026-00 RUBY D JETKOSKI, ET AL 06/13/1990 BK288PR PG 92 WY LINCOLN T025N R112W SEC-0027 LOTS 4(21.68), 5(36.03), 9(25.66), 10(39.93) AND ALL RIPARIAN RIGHTS TO SAID LOTS, S2SW, W2SE T025N R112W SEC-0028 LOTS 8(37.79), 9(14.07) 75034-00 USA WYW-109319 (ROW) 12/28/1988 BK PG WY LINCOLN T026N R111W SEC-0005 SESW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG. SWSE, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG T026N R111W SEC-0008 NENW, THE RIGHT-OF-WAY IS 50 FEET WIDE,1749 FEET LONG 75035-01 BRUCE E JONES, ET UX 06/09/1990 BK288PR PG 86 WY SUBLETTE T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF NWNW OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE,LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY BOUNDARY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W, 1747; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING IN 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET FOR AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17' SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED, WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7' T025N R112W SEC-008 THOSE PORTIONS OF LOTS 3,6, AN 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 THAT PORTION OF THE SWNW AND NWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AND THAT PORTION OF THE SWSW LYING WEST OF THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189; AND NORTH OF THE ACCESS DIRT ROAD LOT 2(17.72), 3(29.79), 6(37.38) AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0018 SENE, NESE AND THAT PORTION OF THE SESE LYING NORTH OF THE ACCESS ROAD T025N R112W SEC-0020 LOTS 2(29.19), 5(9.29), 9(29.12), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 LOTS 1,2 7 75035-2 CECIL R JONES, ET UX 06/09/1990 BK288PR PG 89 WY LINCOLN T025N R112W SEC-0000 A PARCEL OF LAND CONSISTING OF THOSE PORTIONS OF NWN OF SECTION 29, THE W/2W/2 OF SECTION 20, AND THE SWSW OF SECTION 17,AFORESAID TOWNSHIP AND RANGE, LYING EAST OF THE FOLLOWING DESCRIBED LINE (SAID LINE BEING THE WESTERLY RIGHT OF WAY OF THE PROPOSED RELOCATED WYOMING STATE HIGHWAY #189); BEGINNING AT A POINT ON THE SOUTH LINE OF SAID NWNW OF SECTION 29, WHENCE THE NW CORNER OF SAID SECTION 29 BEARS N 40 DEGREES 00' W. 1747'; THENCE ALONG A REGULAR CURVE TO THE RIGHT (THE TANGENT TO THE CURVE AT SAID POINT BEING N 39 DEGREE 55' WEST), HAVING A RADIUS OF 4407.37 FEET OF AN ARC DISTANCE OF 4791.6'; THENCE N 22 DEGREE 20' EAST, 1346.8 FEET; THENCE ALONG A REGULAR CURVE TO THE LEFT WITH A RADIUS OF 3744.7' FOR AN ARC DISTANCE OF 2019.2; THENCE N 81 DEGREE 26' EAST 15 FEET TO A POINT IN SAID SWSW OF SECTION 17, SAID POINT BEING ON THE WESTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 AS NOW CONSTRUCTED. WHENCE THE SW CORNER OF SECTION 17 BEARS SOUTH 47 DEGREE 12' WEST 1661.7 T025N R112W SEC-0008 THOSE PORTIONS OF LOTS 3, 6, AND 7 LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY #189 T025N R112W SEC-0017 LOTS 2(17.72), 3(29.79), 637.38, AND THOSE PORTIONS OF THE SESW, W/2NW AND NWSW, LYING EAST OF THE EASTERLY RIGHT OF WAY BOUNDARY OF WYOMING STATE HIGHWAY # 189 ***SEE SECTION 0000 FOR ACREAGE*** T025N R112W SEC-0019 SESE, NESE AND THAT PORTION OF THE NENE LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189 AND BOUNDED ON THE N BY THAT CERTAIN LINE AS DEEDED IN BOOK 84 PHOTOSTATIC RECORDS AT PAGE 209 IN LINCOLN CO., WY T025N R112W SEC-0020 THAT PORTION OF THE W2W2 LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189, AND BOUNDED ON THE N BY THAT CERTAIN RIGHT OF WAY CENTER LINE AS DEEDED IN BOOK 884 PHOTOSTATIC RECORDS AT PG 209, LINCOLN CO., WY LOTS 2(29.19), 5(9.29), 9(29.12), 10(23.65), NWSE T025N R112W SEC-0021 LOT 1 T025N R112W SEC-0027 LOT 3 T025N R112W SEC-0028 LOT 3-7 T025N R112W SEC-0029 THAT PORTION OF THE NWNW LYING AND BEING SITUATE WESTERLY OF THE W RIGHT OF WAY LINE OF STATE HIGHWAY #189. LOTS 1, 2, 7 75044-00 USA WYW-82343 02/01/1983 BK PG WY SUBLETTE T030N R113W SEC-0005 N2SE, SWSE T030N R113W SEC-0007 NE 75045-00 ARDATH E HARMISON 11/08/1990 BK292 PG 594 WY LINCOLN T025N R112W SEC-0008 LOTS 4, 5, AND 8 T025N R112W SEC-0017 LOT 1 AND NWNE 75046-00 USA WYW-113668 12/01/1988 BK PG WY LINCOLN T025N R114W SEC-0001 LOTS 1-5, 8-11, 13-18, AND W/2 T025N R114W SEC-0002 N2, SE T025N R114W SEC-0003 ALL T025N R114W SEC-0034 TOWNSHIP 25 1/2M-RANGE 114W LOTS 1, 2, 3, 4 T025N R114W SEC-0035 TOWNSHIP 25 1/2N-RANGE 114W LOTS 3, 4 75111-00 USA WYW-125000 10/01/1991 BK 87 PG 720 WY SUBLETTE T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 T027N R112W SEC-0003 LOTS 1, 6, 7, 10, 11 75115-00 USA W-26615 12/01/1970 BK PG WY SUBLETTE T028N R114W SEC-0005 SWSE E - RECORD TITLE 75121-00 USA WY-43217 02/01/1974 BK PG WY SUBLETTE T028N R114W SEC-0008 LOT 1 75122-00 USA WY-6317 07/01/1967 BK PG WY SUBLETTE T028N R114W SEC-0005 LOT 11 74127-00 USA WY-320214 11/01/1965 BK PG WY SUBLETTE T029N R114W SEC-0034 N2, N2S2, LOTS 1-4 T029N R114W SEC-0035 N2, N2S2, LOTS 1-4 75171-00 STATE OF WYOMING 89-00105 02/02/1989 BK PG WY LINCOLN T026N R113W SEC-0022 S2SW 75173-00 USA WYW-126688 05/01/1992 BK PG WY LINCOLN T024N R114W SEC-0007 NE T025N R114W SEC-0008 NW T024N R114W SEC-0021 SW 50029-00 USA EV-26176-B 08/01/1950 BK PG WY SUBLETTE T030N R113W SEC-0032 NENE 50031-00 USA W-21127 12/31/1938 BK PG WY SUBLETTE T030N R113W SEC-0027 NW4, S2 T030N R113W SEC-0034 NE 50033-00 USA W-21128 04/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0022 SW 50188-00 USA W-05991 06/01/1951 BK PG WY SUBLETTE T030N R113W SEC-0003 LOTS 1(40.50), 2(39.99), 3(39.95), 4(39.90) T030N R113W SEC-0004 LOTS 1(39.89) 2(39.90) 50271-00 USA W-044101 10/01/1950 BK PG WY LINCOLN T026N R113W SEC-0017 E2 T026N R113W SEC-0020 N2 T026N R113W SEC-0021 N2 57542-00 USA WYW-113640 12/01/1988 BK 82 PG 160 WY SUBLETTE T027N R111W SEC-0012 N/2, E/2SW, SE T027N R111W SEC-0013 N/2 T027N R111W SEC-0024 N/2, SW 57575-00 USA WYW-114336 03/01/1979 BK PG WY SUBLETTE T031N R113W SEC-0030 SE, S2NE 57607-00 MICKELSON GORDON ET UX 11/01/1988 BK 82 PG 289 WY SUBLETTE T031N R113W SEC-0019 S2NE 58006-00 USA WYW-116386 10/01/1984 BK PG WY SUBLETTE T031N R113W SEC-0028 NESW T031N R113W SEC-0033 SENE 58083-00 ALSADE, LTD. 09/09/1989 BK PG WY SUBLETTE T031N R113W SEC-0029 EXISTING ACCESS ROAD LOCATED; SWSE,NWSW,SWNW EITHER SIDE OF CENTERLINE, FOR THE PURPOSE OF INGRESS AND EGRESS ONLY. 58187-00 USA W-117895 11/01/1989 BK 84 PG 597 WY SUBLETTE T031N R113W SEC-0020 NESW, S/2SW, N/2SE, SWSE T031N R113W SEC-0021 SWNW, NESW, W/2SE T031N R113W SEC-0028 N/2NW 75048-00 USA W-107067 02/01/1988 BK PG WY SUBLETTE T025N R114W SEC-0024 LOTS 1-12, W/2 75256-00 USA EV-023768 12/01/1947 BK 31 PG 429 WY SUBLETTE T025N R113W SEC-0020 SWSW 75257-00 USA EV-022879 07/01/1947 BK 30 PG 545 WY SUBLETTE T028N R113W SEC-0019 LOTS 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17 75258-00 USA EV-023328 10/01/1948 BK 33 PG 637 WY SUBLETTE T028N R113W SEC-0030 N2NE 75259-00 USA EV-023553 06/01/1948 BK 33 PG 193 WY SUBLETTE T028N R113W SEC-0030 S2NE 75260-00 USA WY-01495 02/01/1950 BK 34 PG 83 WY SUBLETTE T028N R113W SEC-0018 LOTS 11, 12,13, 14, 15, 16, 17, 18, W2SE 75237-00 ST WY-86-00117 02/02/1986 BK236 PG 470 WY LINCOLN T026N R112W SEC-0016 NW, NWNE, S2NE, S2
PART III TO EXHIBIT A (DELIVERY AGREEMENT) ENRON OIL & GAS COMPANY WELL LISTING DENVER EXHIBIT A GROUP A
WORKING REVENUE WORKING REVENUE INTEREST INTEREST INTEREST INTEREST WELL NAME WELL NUMBER ST COUNTY BPO BPO APO APO BNG 110-09 F CW 00239-70-00-1 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 9-26N-113W ORIGINAL WELLS BNG 110-09 M CW 00239-70-00-2 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SENW 9-26N-113W ORIGINAL WELLS BNG 111-04 F 00239-80-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 4-26N-113W ORIGINAL WELLS BNG 111-04 M 00239-80-00-2 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SWNW 4-26N-113W ORIGINAL WELLS BNG 34-04 F LW 00243-40-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 34-04 M 00243-40-00-2 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 39-04 00243-80-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESE 4-26N-113W ORIGINAL WELLS BNG 42-04 00244-40-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNE 4-26N-113W ORIGINAL WELLS BNG 45-04 00244-70-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENE 4-26N-113W ORIGINAL WELLS BNG 83-09 LW *00249-30-00-1WY LINCOLN 1.0000000 .8330000 1.0000000 .8330000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 9-26N-113W ORIGINAL WELLS BNG 83-09 LW *00249-30-00-2WY LINCOLN 1.0000000 .8330000 1.0000000 .8330000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NENE 9-26N-113W ORIGINAL WELLS CDR CRK 15-05 CW 01981-80-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 815' FNL, 2415' FWL 5-26N-113W LOT 3 ORIGINAL WELLS CDR CRK 16-05 CW 01981-90-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1950' FNL & 1800' FEL 5-26N-113W (LOT 7) ORIGINAL WELLS CDR CRK 17-05 CW 02139-50-00-1 WY LINCOLN .6000000 .5113528 .6000000 .5113528 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 796' FNL, 900' FEL 5-26N-113W (LOT 1) ORIGINAL WELLS COW HOLLOW 21 LW 02187-50-00-1 WY LINCOLN .0362000 .0256990 .0250000 .0209380 OPERATOR: BANNON ENERGY INC. FORMATION: FRONTIER DESCRIPTION: SENE8-22N-112W 1780' FNL & 660' FEL ORIGINAL WELLS E ST CAN CW 00163-10-00-1 WY LINCOLN 1.0000000 .8470250 1.0000000 .8470250 20-13 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1664' FNL, 1120' FEL 13-26N-112W LOT 2, SENE ORIGINAL WELLS ELB 10-04 PW 00769-00-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 4-26N-112W ORIGINAL WELLS ELB 11-05 PW 00769-10-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 5-26N-112W ORIGINAL WELLS ELB 23-05 PW 00770-70-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 5-26N-112W ORIGINAL WELLS ELB 24-05 PW 00770-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 5-26N-112W ORIGINAL WELLS ELB 34-08 PW 00771-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 8-26N-112W ORIGINAL WELLS ELB 35-05 PW 00771-90-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESW 5-26N-112W ORIGINAL WELLS ELB 36-08 PW 00772-00-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 8-26N-112W ORIGINAL WELLS ELB 37-04 PW 00772-10-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 4-26N-112W ORIGINAL WELLS ELB 59-04D PW 02147-50-00-1 WY LINCOLN .5137380 .4433424 .5137380 .4433424 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 738' FSL, 936' FEL 4-26N-112W SESE ORIGINAL WELLS ELB 61-05 PW 01912-80-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 5-26N-112W ORIGINAL WELLS ELB 62-05 PW 00151-80-00-1 WY LINCOLN 1.0000000 .8656687 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 14 5-26N-112W ORIGINAL WELLS ELB 63-08 PW 00151-90-00-1 WY LINCOLN 1.0000000 .8646549 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 14 8-26N-112W ORIGINAL WELLS ELB 9-08 PW 00773-40-00-1 WY LINCOLN .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 8 8-26N-112W ORIGINAL WELLS ESU 1-21 PW *00779-20-00-1 WY LINCOLN .9361700 .7559590 .9361700 .7559590 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 21-23N-112W ORIGINAL WELLS FONTENELLE 02003-70-00-1 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 RES 1-22 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1495' FNL, 1120' FEL 22-25N-112W SENE ORIGINAL WELLS FONTENELLE *00913-00-00-1 WY LINCOLN .0000000 .0045000 .0720000 .0594000 22-22B OPERATOR: PG&E RESOURCES COMPANY FORMATION: FRONTIER DESCRIPTION: SENW-22-26N-112W (STEAD CANYON PROSPECT ORIGINAL WELLS GRB B 1-1 PW 00144-00-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1366' FNL, 1664' FWL 1-26N-113W LOT 37, SENW ORIGINAL WELLS GRB B 10-12 PW 01975-80-00-1 WY LINCOLN 1.0000000 .8551525 1.0000000 .8551525 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 234' FNL, 2734' FEL 12-26N-113W LOT 37, NENW ORIGINAL WELLS GRB B 11-30 LW 02139-60-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 560' FWL, 1900' FNL 30-27N-112W LOT 2, SWNW ORIGINAL WELLS GRB B 13-30 LW 02139-70-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 200' FSL & 1200' FWL, SESW, 30-27N-112W ORIGINAL WELLS GRB B 14-31 LW 02139-80-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 925' FNL & 120 FWL, LOT 3 (NWNW), 31-27N-112W ORIGINAL WELLS GRB B 7-1 PW 01975-60-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 560' FEL & 2224' FNL (LOT 37) 1-26N-113W ORIGINAL WELLS GRB B 9-1 PW 01975-70-00-1 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2785' FEL & 3610' FNL, LOT 37, (SENW), 1-26N-113W ORIGINAL WELLS GRB CP-1 PW 00945-50-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 7-26N-112W ORIGINAL WELLS GRB CP-2 PW 00945-60-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 18-26N-112W ORIGINAL WELLS GRB CP-5 00945-70-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 6-26N-112W ORIGINAL WELLS GRB T 19-03 PW *00946-60-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: LOT 8 3-26N-113W ORIGINAL WELLS GRB T 22-03 PW *00946-90-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: LOT 9 3-26N-113W ORIGINAL WELLS GRB T 23-03 PW *00947-00-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 3-26N-113W, NESE ORIGINAL WELLS GRB T 31-02 PW *00947-80-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 2-26N-113W, NWNW ORIGINAL WELLS GRB T 34-03 PW *00948-10-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 3-26N-113W, SESE ORIGINAL WELLS GRB T 49-10 PW *00949-20-00-1 WY LINCOLN .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 10-26N-113W, NENE ORIGINAL WELLS GRB T 50-10 LW *00949-50-00-1 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 10-26N-113W, SENE ORIGINAL WELLS GRB 12-07 00952-10-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 7-26N-112W ORIGINAL WELLS GRB 136-18 F PW 02139-90-00-1 WY LINCOLN .9198070 .6798948 .9198070 .6798489 (T) OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 334' FNL & 1910' FWL, 18-26N-112W, NENW ORIGINAL WELLS GRB 136-7 F 00159-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 (PROP) OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 334' FNL & 1910' FWL, 18-26N-112W, NENW ORIGINAL WELLS GRB 137-18 F PW 02140-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2600' FNL & 150' FWL, LOT 2(SWNW) 18-26N-112W ORIGINAL WELLS GRB 138-18 F PW 02140-10-00-2 WY LINCOLN .9180700 .7792040 .9198070 .7792040 (C) OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1642' FEL & 2058' FNL SWNE 18-26N-112W ORIGINAL WELLS GRB 138-18 F PW 02140-10-00-1 WY LINCOLN .9180700 .7792040 .9198070 .7792040 (T) OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1642' FEL & 2058' FNL, SWNE, 18-26N-112W ORIGINAL WELLS GRB 141-01 BR PW 00158-40-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 550' FNL & 1500' FEL (NWNE) SEC 1-26N-113W ORIGINAL WELLS GRB 141-01 F PW 00158-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 550' FNL & 1500' FEL (NWNE) SEC 1-26N-113W ORIGINAL WELLS GRB 148-2 BR PW 00158-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER/35% ALLOCATION DESCRIPTION: 400' FSL & 2350' FWL, 2-26N-113W, SESW ORIGINAL WELLS GRB 148-2 F PW 00158-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: ENRON OIL & GAS FORMATION: FRONTIER A-B / 65% ALLOC DESCRIPTION: 400' FSL & 2350' FWL, 2-26N-113W, SESW ORIGINAL WELLS GRB 149-10 BR LW 01985-40-00-2 WY LINCOLN 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 1770' FNL & 358' FEL, SEC. 10-26N-113W, (SENE) ORIGINAL WELLS GRB 149-10 F PW 01985-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1770' FNL & 358' FEL, SEC. 10-26N-113W, (SENE) ORIGINAL WELLS GRB 150-10 PW 02006-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1790' FSL & 500' FEL, NESE, 10-26N-113W ORIGINAL WELLS GRB 159-13 PW 01985-50-00-1 WY LINCOLN .9198070 .7792080 .9198070 .7792080 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 800' FWL & 2100' FNL, SWNW, 13-26N-113W ORIGINAL WELLS GRB 160-14 PW 01985-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2398' FNL & 2330' FEL, SWNE, 14-26N-113W ORIGINAL WELLS GRB 166-18 PW 00952-60-00-1 WY LINCOLN 1.0000000 .7211968 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 497' FWL & 635' FSL, SEC. 18-26N-112W, (LOT 4) ORIGINAL WELLS GRB 17-11 BR PW 00952-70-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWSE 11-26N-113W ORIGINAL WELLS GRB 17-11 F PW 00952-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 11-26N-113W ORIGINAL WELLS GRB 173-15 F PW 02140-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 400' FEL & 1570' FNL, SENE, 15-26N-113W ORIGINAL WELLS GRB 175-10 PW 02006-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 50' FSL & 50' FEL, 10-26N-113W, SESE ORIGINAL WELLS GRB 18-01 BR PW 00952-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENW 1-26N-113W ORIGINAL WELLS GRB 18-01 F PW 00952-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 1-26N-113W ORIGINAL WELLS GRB 188-22 F PW 02140-30-00-1 WY LINCOLN 1.0000000 .8472298 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 590' FNL & 600' FEL, LOT 1(NENE) 22-26N-113W ORIGINAL WELLS GRB 2-12 PW 00953-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 12-26N-113W ORIGINAL WELLS GRB 23-02 BR PW 00953-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWNW 2-26N-113W ORIGINAL WELLS GRB 23-02 F PW 00953-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 2-26N-113W ORIGINAL WELLS GRB 24-02 PW 00953-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 2-26N-113W ORIGINAL WELLS GRB 25-02 F PW 00953-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 2-26N-113W ORIGINAL WELLS GRB 27-14 PW 00953-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 14-26N-113W ORIGINAL WELLS GRB 30-15 PW 00954-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 15-26N-113W ORIGINAL WELLS GRB 30-15 LW 00954-40-00-2 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 BAXTER OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESE 15-26N-113W ORIGINAL WELLS GRB 34-06 PW 00954-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 6-26N-112W ORIGINAL WELLS GRB 4-13 PW 00955-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 13-26N-113W ORIGINAL WELLS GRB 42-13 PW 00955-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 13-26N-113W ORIGINAL WELLS GRB 43-11 F PW 00955-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 11-26N-113W ORIGINAL WELLS GRB 43-11 M PW 00955-60-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNW 11-26N-113W ORIGINAL WELLS GRB 44-14 PW 00955-70-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 14-26N-113W ORIGINAL WELLS GRB 44-14 LW 00955-70-00-2 WY LINCOLN 1.0000000 .8450000 1.0000000 .8450000 BAXTER OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENW 14-26N-113W ORIGINAL WELLS GRB 45-12 PW 00955-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 12-26N-113W ORIGINAL WELLS GRB 46-01 PW 00955-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 1-26N-113W ORIGINAL WELLS GRB 47-02 PW 00956-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 2-26N-113W ORIGINAL WELLS GRB 51-01 PW 00956-40-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: LOT 37 1-26N-113W ORIGINAL WELLS GRB 53-23 LW 00956-60-00-2 WY LINCOLN 1.0000000 .8350000 1.0000000 .8350000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNW 23-26N-113W ORIGINAL WELLS GRB 53-23 PW 00956-60-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNW 23-26N-113W ORIGINAL WELLS GRB 55-01 BR PW 00956-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 1-26N-113W ORIGINAL WELLS GRB 55-01 F PW 00956-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 1-26N-113W ORIGINAL WELLS GRB 58-18 PW 00957-00-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 18-26N-112W ORIGINAL WELLS GRB 64-11 BR PW 00957-80-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWNE 11-26N-113W ORIGINAL WELLS GRB 64-11 F PW 00957-80-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 11-26N-113W ORIGINAL WELLS GRB 65-14 PW 00957-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 14-26N-113W ORIGINAL WELLS GRB 71-06 PW 00958-70-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 6-26N-112W ORIGINAL WELLS GRB 76-14 BR PW 00959-20-00-2 WY LINCOLN .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 14-26N-113W ORIGINAL WELLS GRB 76-14 F PW 00959-20-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 14-26N-113W ORIGINAL WELLS GRB 77-13 PW 00959-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 13-26N-113W ORIGINAL WELLS GRB 78-13 PW 00959-40-00-1 WY LINCOLN 1.0000000 .8461968 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 13-26N-113W ORIGINAL WELLS GRB 79-12 PW 00959-50-00-3 WY LINCOLN 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1320' FNL & 1320' FEL, NENE, 12-26N-113W ORIGINAL WELLS GRB 79-12 BR LW 00959-50-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 12-26N-113W ORIGINAL WELLS GRB 79-12 F PW 00959-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1320' FNL & 1320' FEL, SEC. 12-26N-113W, (NENE) ORIGINAL WELLS GRB 80-07 BR LW 00959-70-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENW 7-26N-112W ORIGINAL WELLS GRB 80-07 F PW 00959-70-00-1 WY LINCOLN .9198070 .7792040 .9898070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 7-26N-112W ORIGINAL WELLS GRB 82-6 PW 00959-90-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 800' FWL & 2200' FNL, SENW, 6-26N-112W ORIGINAL WELLS GRB 83-07 BR LW 00960-00-00-2 WY LINCOLN 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSW 7-26N-112W ORIGINAL WELLS GRB 83-07 F PW 00960-00-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 7-26N-112W ORIGINAL WELLS GRB 84-18 PW 00960-10-00-1 WY LINCOLN .9198070 .6542040 .9198070 .6542040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 18-26N-112W ORIGINAL WELLS GRB 85-12 PW 00960-30-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSW 12-26N-113W ORIGINAL WELLS GRB 87-11 PW 00960-50-00-1 WY LINCOLN .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 11-26N-113W ORIGINAL WELLS HANSON *00984-30-00-1 WY LINCOLN .5000000 .4075000 .5000000 .4075000 FEDERAL OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER 40-06 DESCRIPTION: 2882' FNL, & 968' FEL, SEC. 6-26N-11W, (NESE) ORIGINAL WELLS HYRUM DITCH CW *01011-50-00-1 WY LINCOLN .0000000 .0110690 .0000000 .0110690 11X26 OPERATOR: FMC CORPORATION FORMATION: FRONTIER DESCRIPTION: PT RE-SURV LOT 44 & 45, LOTS 3 & 4-26&27-T26N-113W ORIGINAL WELLS HYRUM DITCH CW *00011-60-00-1 WY LINCOLN .0000000 .0058330 .0000000 .0000000 31X26 OPERATOR: FMC CORPORATION FORMATION: FRONTIER DESCRIPTION: LOT 7, 8, PT LOTS 41 & 43-26-T26N-R113W ORIGINAL WELLS LANSDALE FED CW 01932-70-00-1 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 10-8 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LANSDALE FED CW 01932-70-00-2 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 10-8 OPERATOR: EOG FORMATION: 2ND FRONTIER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LANSDALE FED CW 01932-70-00-3 WY LINCOLN .0000000 .0000000 1.0000000 .8600000 10-8 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENW 8-26N-111W ORIGINAL WELLS LARSON 1-17 LW *01031-50-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 17-26N-112W ORIGINAL WELLS MCGINNIS 1-17 LW *01071-70-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 17-26N-112W ORIGINAL WELLS OPAL 4-21 LW *00472-80-00-1 WY LINCOLN 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 21-22N-112W ORIGINAL WELLS SHB 1-08(F) CW 00519-20-00-2 WY LINCOLN .9500000 .7748750 .9500000 .7748750 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1308 FNL 1388 FEL NWNE-8-26N-113W (HOGBACK PROSPECT) ORIGINAL WELLS SHB34-08 CW *00615-10-00-1 WY LINCOLN .2500000 .2025000 .2500000 .2025000 OPERATOR: MOBIL OIL CORPORATION FORMATION: BEAR RIVER/MUDDY DESCRIPTION: E2-8-26N-113W ORIGINAL WELLS SHB 12-04 CW 00515-60-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 12 4-26N-113W ORIGINAL WELLS SHB 13-08A CW 00515-70-00-1 WY LINCOLN .9459459 .7714898 .9500000 .7748750 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NW SE 8-26N-113W ORIGINAL WELLS SHB 15-04 CW 00515-80-00-2 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 15-04 CW 00515-80-00-3 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 (FRONT) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 15-04 CW 00515-80-00-1 WY LINCOLN 1.0000000 .8418228 1.0000000 .8418228 (MUD) OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 1602' FWL & 548' FNL4-26N-113W LOT 3 ORIGINAL WELLS SHB 21-04 00515-90-00-1 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 10 4-26N-113W ORIGINAL WELLS SHB 21-04 00515-90-00-2 WY LINCOLN 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: LOT 10 4-26N-113W ORIGINAL WELLS SHB 3-16 F 00519-30-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNW 16-26N-113W ORIGINAL WELLS SHB 3-16 M 00519-30-00-2 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SWNW 16-26N-113W ORIGINAL WELLS SHB 4-09 F 00519-50-00-2 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 9-26N-113W ORIGINAL WELLS SHB 4-09 M 00519-50-00-1 WY LINCOLN 1.0000000 .8216250 1.0000000 .8216250 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWSW 9-26N-113W ORIGINAL WELLS SHB 5-16 LW 00519-60-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SW 16-26N-113W ORIGINAL WELLS SHB 6-16 00519-70-00-1 WY LINCOLN 1.0000000 .7750000 1.0000000 .7750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 16-26N-113W ORIGINAL WELLS SLB 1-04 (CW) 00528-30-00-1 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: LOT 11 4-26N-113W ORIGINAL WELLS SLB 1-04 (CW) 00528-30-00-2 WY LINCOLN .6250000 .5125000 .6250000 .5125000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 11 4-26N-113W ORIGINAL WELLS SPR CRK 7-14 00570-20-00-1 WY LINCOLN .0000000 .0000000 .0000000 .0000000 LW P&A OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 14-26N-112W ORIGINAL WELLS ST CAN 1-15 00586-30-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NENE 15-26N-112W ORIGINAL WELLS ST CAN 19-13 LW *00587-10-00-2 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1515' FSL & 3455' FWL, NWSE, 13-26N-112W ORIGINAL WELLS ST CAN 19-13 PW 00587-10-00-1 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: FRONTIER B DESCRIPTION: 1515' FSL & 3455' FWL, NWSE, 13-26N-112W ORIGINAL WELLS ST CAN 3-13 LW 00587-30-00-2 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2240' FNL & 1104" FEL, SEC. 13-26N-112W, (SESW) ORIGINAL WELLS ST CAN 3-13 PW 00587-30-00-1 WY LINCOLN 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: FRONTIER B DESCRIPTION: SESW 13-26N-112W ORIGINAL WELLS ST CAN 5-14 LW 00587-50-00-2 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 BAX OPERATOR: EOG FORMATION: BAXTER(RECOMPLETION) DESCRIPTION: 50' FNL & 650' FEL, SEC. 14, 26N, 112W, (NE NE) ORIGINAL WELLS ST CAN 5-14 00587-50-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 LW(TA) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 50' FNL & 650' FEL, SEC. 14-26N-112W, (NENE) ORIGINAL WELLS ST CAN 6-10 00587-60-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NWSE 10-26N-112W ORIGINAL WELLS ST CAN 7-10 00587-70-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: SWSW 10-26N-112W ORIGINAL WELLS ST CAN 8-11 PW 00587-80-00-3 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2496' FSL & 429' FWL 11-26N-112W NWSW ORIGINAL WELLS ST CAN 8-11 F 00587-80-00-2 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER "A" DESCRIPTION: NWSW 11-26N-112W ORIGINAL WELLS ST CAN 9-11 LW 00588-00-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1350' FWL & 950' FNL, 11-26N-112W, (N2NW) ORIGINAL WELLS W ST CAN 12-9 LW 00817-90-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1203' FNL & 1414' FWL, SEC. 9-26N-112W, (NWNW) ORIGINAL WELLS W ST CAN LW 01989-30-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 13-09 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1127' FSL & 769' FWL, SEC. 9-26N-112W, (SWSW) ORIGINAL WELLS W ST CAN 14-9 00149-60-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2130' FNL & 1450' FEL, SEC. 9-26N-112W, (SWNE) ORIGINAL WELLS W ST CAN LW 01989-40-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 15-09 OPERATOR: EOG FORMATION: 2ND FRONTIER DESCRIPTION: 1538' FSL & 1920' FEL, SEC 9-26N-112W, (NWSE) ORIGINAL WELLS W ST CAN LW *02140-90-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 17-9D OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1225' FNL, 1197' FWL 9-26N-112W NWNW ORIGINAL WELLS W ST CAN LW 02134-80-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 18-17 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 17-26N-112W ORIGINAL WELLS W ST CAN LW 02141-00-00-1 WY LINCOLN 1.0000000 .8650000 1.0000000 .8650000 20-9D OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2500' FSL, 1900' FWL 9-26N-112W NESW ORIGINAL WELLS WEST SWAN CW 02130-50-00-1 WY LINCOLN 1.0000000 .8371750 1.0000000 .8371750 1-24 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 553' FEL, 953' FNL 24-25N-112W LOT 1 ORIGINAL WELLS WEST SWAN LW 02138-00-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 2-25 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 550'FEL, 2180'FSL 25-25N-112W LOT 3 ORIGINAL WELLS WEST SWAN LW 02141-10-00-1 WY LINCOLN 1.0000000 .8250000 1.0000000 .8250000 3-25 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2155' FWL & 2109' FSL 25-25N-112W NESW ORIGINAL WELLS WILLOW CREEK PW *00831-10-00-1 WY LINCOLN .7500000 .6333050 .7500000 .6333605 1-03 OPERATOR: EOG FORMATION: FORT UNION DESCRIPTION: NWNW 3-24N-114W ORIGINAL WELLS
ENRON OIL & GAS COMPANY WELL LISTING DENVER EXHIBIT A GROUP A
WORKING REVENUE WORKING REVENUE INTEREST INTEREST INTEREST INTEREST WELL NAME WELL NUMBER ST COUNTY BPO BPO APO APO AMOCO AG-1/ *00110-90-00-1 WY SUBLETTE .0000000 .0026760 .0446015 FED 40-18 .0347892 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: SE 18-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS AMOCO AH-1/ *00111-00-00-1 WY SUBLETTE .0000000 .0055980 .0711640 FED 20-19 .0561719 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: NENE 19-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS AMOCO AJ-1/ *00110-80-00-1 WY SUBLETTE .0000000 .0026760 .0446015 FED.20-18 .0347892 OPERATOR: AMOCO PRODUCTION COMPANYFORMATION: FRONTIER AND BEAR RIVER DESCRIPTION: NE 18-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS B & H 1-01 LW 00730-00-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 01-27N-114W ORIGINAL WELLS B 1A-22 LW *00730-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 22-29N-113W ORIGINAL WELLS B 11TC-14LW 00200-00-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 (TA) OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 14-29N-113W ORIGINAL WELLS B 15A-11 LW *00200-10-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWSW 11-29N-113W, ORIGINAL WELLS B 16-15 LW *00200-20-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 15-29N-113W ORIGINAL WELLS B 18-02 LW *00200-40-00-1 WY SUBLETTE 1.0000000 .7912500 1.0000000 .7912500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSW 2-29N-113W ORIGINAL WELLS B 22-25 LW *00200-60-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 25-29N-113W ORIGINAL WELLS B 26-14 LW&*00200-70-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 14-29N-113W ORIGINAL WELLS B 3-23 LW *00201-00-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 23-29N-113W ORIGINAL WELLS B 30-25 LW *00201-10-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENE 25-29N-113W ORIGINAL WELLS B 33-10 LW *00201-40-00-1 WY SUBLETTE 1.0000000 .7412500 1.0000000 .7412500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 10-29N-113W ORIGINAL WELLS B 36-25 PW *00201-50-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESW 25-29N-113W ORIGINAL WELLS B 39-11 LW *00201-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 11-29N-113W ORIGINAL WELLS B 4-26 LW *00201-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NESW 26-29N-113W ORIGINAL WELLS B 43-24 LW *00201-90-00-1 WY SUBLETTE 1.0000000 .8475000 1.0000000 .8475000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 24-29N-113W ORIGINAL WELLS B 44-25 00202-00-00-1 WY SUBLETTE 1.0000000 .8375000 1.0000000 .8375000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 25-29N-113W ORIGINAL WELLS B 45-02 LW *00202-10-00-1 WY SUBLETTE 1.0000000 .7912500 1.0000000 .7912500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 2-29N-113W ORIGINAL WELLS B 5-35 LW *00202-40-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 35-29N-113W ORIGINAL WELLS B 5A-35 LW *00202-50-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 35-29N-113W ORIGINAL WELLS B 57-23 PW *00202-70-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESE 23-29N-113W ORIGINAL WELLS B 62-14 LW 00203-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-29N-113W ORIGINAL WELLS B 63-26 00203-10-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 26-29N-113W ORIGINAL WELLS B 65-23LW (TA) *00203-20-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNE 23-29N-113W ORIGINAL WELLS B 68-14 LW *00203-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-29N-113W ORIGINAL WELLS B 69 TC-03 00203-40-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: TRANSITION (TUBING) DESCRIPTION: SWNE 3-29N-113W ORIGINAL WELLS B 69 TC-03 00203-40-00-2 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: ALMY (CASING) DESCRIPTION: SWNE 3-29N-113W ORIGINAL WELLS B 70-14LW (TA) &*00203-50-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 14-29N-113W ORIGINAL WELLS B 71-14LW (TA) &*00203-60-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 14-29N-113W ORIGINAL WELLS B 81-24LW (TA) *00203-70-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNW 24-29N-113W ORIGINAL WELLS B 82-24 LW *00203-80-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 24-29N-113W ORIGINAL WELLS B 9-14 LW&*00204-10-00-2 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 875' FNL & 780' FWL, SEC. 14-29N-113W, (NWNW) ORIGINAL WELLS B 9A-14 LW 00204-10-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNW 14-29N-113W ORIGINAL WELLS BESS CANYON 01988-70-00-1 WY SUBLETTE 1.0000000 .8650000 1.0000000 .8650000 5-35 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 760' FNL & 460' FEL, SEC. 35-27N-112W, (NENE) ORIGINAL WELLS BIG PINEY MV *99999-99-99-N WY SUBLETTE 1.0000000 .8571348 1.0000000 .8571348 LABARGE OPERATOR: EOG FORMATION: MESV TRANS/M SAND DESCRIPTION: MESAVERDE TRANSITION/M SAND (TIP TOP SHALLOW UNIT) ORIGINAL WELLS BIRD CANYON *00108-80-00-1 WY SUBLETTE .2121756 .1644361 .2121756 .1644361 FED 20-6 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: NE 6-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS BIRD STATE LW *00229-60-00-1 WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 1-16 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 16-27N-112W ORIGINAL WELLS BIRD STATE LW *00229-70-00-1 WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 2-16 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 16-27N-112W ORIGINAL WELLS BIRD STATE LW&*00229-80-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 3-16 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NW 16-27N-112W ORIGINAL WELLS BNG70-28 LW *00247-80-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 1-28 LW *00238-60-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: MEASAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 101-33 PW&*00238-80-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS BNG 102-33 PW&*00238-90-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS BNG 104-33 PW&*00239-10-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, NWSW ORIGINAL WELLS BNG 105-04 PW&*00239-20-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NENW ORIGINAL WELLS BNG 106-04 WIW &*00239-30-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: NWNW 4-27N-113W ORIGINAL WELLS BNG 107-32 PW *00239-40-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, SESE ORIGINAL WELLS BNG 11-23 LW 00239-60-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 23-28N-113W ORIGINAL WELLS BNG 112-21 PW *00239-90-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 114-28 PW *00240-10-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NWNW ORIGINAL WELLS BNG 115-21 PW *00240-20-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, NESW ORIGINAL WELLS BNG 116-28 PW *02007-90-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 118-20 PW *00240-50-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 20-28N-113W, SESW ORIGINAL WELLS BNG 15-32 PW 00241-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 32-28N-113W, NESE ORIGINAL WELLS BNG 16-05 PW 00241-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, NENE ORIGINAL WELLS BNG 17-05 PW 00241-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, SESE ORIGINAL WELLS BNG 18-17 PW 00241-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, SWNE ORIGINAL WELLS BNG 19-08 PW 00241-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NWSW ORIGINAL WELLS BNG 2-28 LW *00241-90-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NWSE ORIGINAL WELLS BNG 20-32 LW *00242-00-00-1 WY SUBLETTE 1.0000000 .7850000 1.0000000 .7850000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 32-28N-113W ORIGINAL WELLS BNG 21-20 PW 00242-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, NENE ORIGINAL WELLS BNG 22-05 PW 00242-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, SWSW ORIGINAL WELLS BNG 25-09 PW 00242-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SESW ORIGINAL WELLS BNG 26-21 PW 00242-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENE ORIGINAL WELLS BNG 27-04 PW 00242-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 4-27N-113W, SESW ORIGINAL WELLS BNG 28-33 PW 00242-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SESE ORIGINAL WELLS BNG 29-33 PW 00242-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS BNG 30-28 FVPU00243-10-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS BNG 30-28 MVPU00243-10-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS BNG 31-21 LW 00243-20-00-1 WY SUBLETTE .5000000 .4375000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENW 21-27N-112W ORIGINAL WELLS BNG 36-16 PW 00243-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SENE ORIGINAL WELLS BNG 37-33 00243-60-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NESE, SEC. 33-27N-113W ORIGINAL WELLS BNG 37-33 LW 00243-60-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWSE 33-27N-113W ORIGINAL WELLS BNG 37-33 LW 00243-60-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2640' FNL & 1330' FEL 33-27N-113W NESE ORIGINAL WELLS BNG 37-33 LW 00243-60-00-4 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWSE 33-27N-113W ORIGINAL WELLS BNG 38-09 PW 00243-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SWNW ORIGINAL WELLS BNG 40-32 PW&*00244-20-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, NESE ORIGINAL WELLS BNG 41-28 PW *00244-30-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, NENW ORIGINAL WELLS BNG 43-28 VPU 00244-50-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, NESW ORIGINAL WELLS BNG 46-28 PW *00244-80-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRANS/M SAND DESCRIPTION: SEC. 28-28N-113W, NWNW ORIGINAL WELLS BNG 47C-33 &*00245-00-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWSW 33-28N-113W ORIGINAL WELLS BNG 49-33 PW 00245-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SESW ORIGINAL WELLS BNG 5-08 PW 00245-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, SESE ORIGINAL WELLS BNG 50-16 PW 00245-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SWNW ORIGINAL WELLS BNG 50-16 LW 00245-50-00-2 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1000' FWL & 1425' FNL, 16-27N-113WSWNW ORIGINAL WELLS BNG 51-04 PW 00245-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 4-27N-113W, SENW ORIGINAL WELLS BNG 53-29 PW *00245-80-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 29-28N-113W, NENE ORIGINAL WELLS BNG 54-28 PW *00245-90-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 55-33 PW&*00010-00-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 33-28N-113W, SWSW ORIGINAL WELLS BNG 56-20 PW *00246-10-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 20-28N-113W, SWSE ORIGINAL WELLS BNG 59-32 &*00246-40-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SENE 32-28N-113W ORIGINAL WELLS BNG 6-33 LW *00246-50-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 33-28N-113W ORIGINAL WELLS BNG 63-29 PW *00246-80-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNE ORIGINAL WELLS BNG 69-33 &*00247-30-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 WIW OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSW 33-28N-113W ORIGINAL WELLS BNG 71-32 &*00247-90-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SESE 32-28N-113W ORIGINAL WELLS BNG 72-33 &*00248-10-00-1 WY SUBLETTE 1.0000000 .7777791 1.0000000 .7777791 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWNW 33-28N-113W ORIGINAL WELLS BNG 75-28 PW *00248-30-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRANS/M SAND DESCRIPTION: SEC. 28-28N-113W, SWNW ORIGINAL WELLS BNG 76-21 PW *00248-40-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 77-21 PW *00248-50-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 21-28N-113W, NWSW ORIGINAL WELLS BNG 80-32 PW&*00249-00-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 32-28N-113W, SESE ORIGINAL WELLS BNG 81-08 PW 00249-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NESE ORIGINAL WELLS BNG 82-28 LW *00249-20-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SEC. 28-28N-113W, SENW ORIGINAL WELLS BNG 84-04 PW&*00249-40-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NENW ORIGINAL WELLS BNG 86-04 PW&*00249-50-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, SENW ORIGINAL WELLS BNG 88-04 PW&*00249-60-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NESW ORIGINAL WELLS BNG 90TC-04 &*00249-90-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SWNW 4-27N-113W ORIGINAL WELLS BNG 92-28 B 00250-00-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 860' FSL & 2700' FEL28-27N-113WSESW ORIGINAL WELLS BNG 92-28 F 00250-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESW 28-27N-113W ORIGINAL WELLS BNG 92-28 M 00250-00-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESW 28-27N-113W ORIGINAL WELLS BNG 93-20 LW *00250-10-00-1 WY SUBLETTE .5000000 .4375000 .5000000 .4375000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 20-27N-112W ORIGINAL WELLS BNG 94A-21 PW *02018-00-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 21-28N-113W, SWSW ORIGINAL WELLS BNG 97-21 PW *00250-60-00-1 WY SUBLETTE 1.0000000 .8571349 1.0000000 .8571349 OPERATOR: EOG FORMATION: MESAVERDE TRAN/M SAND DESCRIPTION: SEC. 21-28N-113W, NWSW ORIGINAL WELLS BNG 98-04 PW&*00250-70-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: SEC. 4-27N-113W, NWNW ORIGINAL WELLS BNG 99-04 &*00250-80-00-1 WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 WIW OPERATOR: EOG FORMATION: MESAVERDE 5TH ZONE DESCRIPTION: NESW 4-27N-113W ORIGINAL WELLS BPMV 15-12 PW *00265-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 1-11A PW&*00261-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SWSE) ORIGINAL WELLS BPMV 1-11A PW&*00261-00-00-2 WY SUBLETTE .5487000 .4632169 .5487000 .4632169 (TRAN) OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SWSE) ORIGINAL WELLS BPMV 1-58 PW&*00261-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SWSE) ORIGINAL WELLS BPMV 1-59 PW&*00261-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (NWNE) ORIGINAL WELLS BPMV 1-62 PW&*00261-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SESW) ORIGINAL WELLS BPMV 1-62 PW&*00261-30-00-2 WY SUBLETTE .5487000 .4632169 .5487000 .4632169 (TRANS) OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SESW) ORIGINAL WELLS BPMV 1-64 PW&*00261-40-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (SENW) ORIGINAL WELLS BPMV 1-64 PW&*00261-40-00-2 WY SUBLETTE .5487000 .4632169 .5487000 .4632169 (TRANS) OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 14-29N-113W (SENW) ORIGINAL WELLS BPMV 1-65 PW&*00261-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SWNE) ORIGINAL WELLS BPMV 1-66 PW&*00261-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (NWSE) ORIGINAL WELLS BPMV 1-67 PW&*00261-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (NESW) ORIGINAL WELLS BPMV 1-83 PW&*00261-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 14-29N-113W (NESW) ORIGINAL WELLS BPMV 1-84 WIW PW&*00261-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 23-29N-113W (SESE) ORIGINAL WELLS BPMV 10-01WIW PW *00262-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWNW) ORIGINAL WELLS BPMV 11-56 PW *00262-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 26-29N-113W (NENE) ORIGINAL WELLS BPMV 13-01 PW *00262-40-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-34 PW *00262-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-49 PW *00262-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (SWSW) ORIGINAL WELLS BPMV 13-53 TA *00263-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW PW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (NWSW) ORIGINAL WELLS BPMV 13-86 PW *00263-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 25-29N-113W (NWSW) ORIGINAL WELLS BPMV 14-01 PW *00263-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS BPMV 14-02 PW *00263-40-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS BPMV 14-33 PW *00263-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 (WIW) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-34 PW *00263-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-36 PW *00263-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NWNE) ORIGINAL WELLS BPMV 14-38 PW *00263-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SWNE) ORIGINAL WELLS BPMV 14-42 PW *00264-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 (WIW) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS BPMV 14-43 PW *00264-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 14-48 PW *00264-40-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (NENE) ORIGINAL WELLS BPMV 14-49 PW *00264-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 14-51 TA *00264-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW PW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 14-74 PW&*00264-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (SENW) ORIGINAL WELLS BPMV 14-75 PW *00264-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SWNE) ORIGINAL WELLS BPMV 14-76 PW *00265-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 3-28N-113W (SENE) ORIGINAL WELLS BPMV 15-02 PW *00266-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSW) ORIGINAL WELLS BPMV 15-04 PW *00267-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NENW) ORIGINAL WELLS BPMV 15-07 PW *00268-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 15-08 PW *00268-20-00-1 WY SUBLETTE .4722000 .4623532 .4722000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 36-29N-113WNWSW ORIGINAL WELLS BPMV 15-1 PW *00265-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC. 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-13 *00265-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 PW (TA) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSW) ORIGINAL WELLS BPMV 15-15 PW *00265-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-16 *00265-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 PW (TA) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-17 PW *00265-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS BPMV 15-18 *00265-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 PW (TA) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-19 *00266-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 PW (TA) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 36-29N-113WSESW ORIGINAL WELLS BPMV 15-22 PW *00266-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113 W (SWSW) ORIGINAL WELLS BPMV 15-23 PW *00266-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS BPMV 15-24 PW *00266-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NWNW) ORIGINAL WELLS BPMV 15-25WIW PW *00266-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-27 PW *00266-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-28 PW *00266-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWSE) ORIGINAL WELLS BPMV 15-30 PW *00267-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 (WIW) OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SENW) ORIGINAL WELLS BPMV 15-31 PW *00267-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NENW) ORIGINAL WELLS BPMV 15-32 PW *00267-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SESW) ORIGINAL WELLS BPMV 15-34 PW *00267-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SENW) ORIGINAL WELLS BPMV 15-35 PW *00267-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (SWNW) ORIGINAL WELLS BPMV 15-36 PW *00267-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 36-29N-113W (NESW) ORIGINAL WELLS BPMV 2-35 PW *00268-50-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 35-29N-113W (NESE) ORIGINAL WELLS BPMV 2-38 PW *00268-60-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SEC 35-29N-113W (SESE) ORIGINAL WELLS BPMV 6-37 PW&*00268-70-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 WIW OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SESE) ORIGINAL WELLS BPMV 6-41 PW&*00268-80-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SESE) ORIGINAL WELLS BPMV 6-54 PW&*00268-90-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SENE) ORIGINAL WELLS BPMV 6-55 PW&*00269-00-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (SENE) ORIGINAL WELLS BPMV 6-61 PW&*00269-10-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 26-29N-113W (NESE) ORIGINAL WELLS BPMV 6-70 PW&*00101-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 20-29N-113W (SENE) ORIGINAL WELLS BPMV 8-26 PW&*00270-20-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (NENW) ORIGINAL WELLS BPMV 8-35 WIW PW&*00270-30-00-1 WY SUBLETTE .5487000 .4623532 .5487000 .4623532 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 3-28N-113W (SENW) ORIGINAL WELLS BUDD 1-10 LW&*00287-40-00-1 WY SUBLETTE 1.0000000 .7412500 1.0000000 .7412500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 10-29N-113W ORIGINAL WELLS BURLEY #1 LW 02002-90-00-1 WY SUBLETTE 1.0000000 .8625000 1.0000000 .8625000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1950' FEL & 920' FNL 19-28N-113W NWNE ORIGINAL WELLS C 1-23 LW *00292-90-00-1 WY SUBLETTE 1.0000000 .8557812 1.0000000 .8557812 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 23-18N-113W ORIGINAL WELLS C 18-14 LW *00293-50-00-1 WY SUBLETTE 1.0000000 .8557812 1.0000000 .8557812 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 14-28N-113W ORIGINAL WELLS C 19-23 LW&*00293-60-00-1 WY SUBLETTE 1.0000000 .7500000 1.0000000 .7500000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE 23-28N-113W ORIGINAL WELLS C 23-03 &*00293-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 LW (TA) OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 3-28N-113W ORIGINAL WELLS C 31-25 LW *00294-10-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWNE 25-28N-113W ORIGINAL WELLS C 39-03 &*00294-20-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 LW (TA) OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 43B-03 LW&*00294-50-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 47-22 PW *00294-60-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENE 22-28N-113W ORIGINAL WELLS C 52-22 PW *00295-20-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NESE 22-28N-113W ORIGINAL WELLS C 57-25 LW *00295-50-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 25-28N-113W ORIGINAL WELLS C 63-34 LW *00296-20-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 34-28N-113W ORIGINAL WELLS C 64-33 LW *00296-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENE 33-28N-113W ORIGINAL WELLS C 68-34 LW *00296-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-28N-113W ORIGINAL WELLS C 73-23 LW&*00297-00-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSW 23-28N-113W ORIGINAL WELLS C 74-22 PW&*00297-20-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS C 75-36 LW *00297-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWNE 36-28N-113W ORIGINAL WELLS C 76-25 LW *00297-40-00-1 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 25-28N-113W ORIGINAL WELLS C 78-26 PW&*00297-60-00-1 WY SUBLETTE 1.0000000 .8373973 1.0000000 .8373973 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NWNW 26-28N-113W ORIGINAL WELLS C 84-03 LW&*00298-30-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 3-28N-113W ORIGINAL WELLS C 85-03 LW&*00298-40-00-1 WY SUBLETTE 1.0000000 .8525000 1.0000000 .8525000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 3-28N-113W ORIGINAL WELLS CBU 1-04 PW 00315-30-00-1 WY SUBLETTE 1.0000000 .8263918 1.0000000 .8263918 OPERATOR: EOG FORMATION: FRONTIER A DESCRIPTION: SESE 4-28N-113W ORIGINAL WELLS CBU 11-34 PW 00315-50-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 13-25 PW 00315-70-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NWNE 25-28N-113W ORIGINAL WELLS CBU 14-36 PW 00315-80-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NESW 36-28N-113W ORIGINAL WELLS CBU 16-25 LW 00315-90-00-2 WY SUBLETTE 1.0000000 .8290000 1.0000000 .8290000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWSW 25-28N-113W ORIGINAL WELLS CBU 17-35 PW 00316-00-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SWSE 35-28N-113W ORIGINAL WELLS CBU 18-34 PW 00316-10-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SESW 34-28N-113W ORIGINAL WELLS CBU 19-34 PW 00316-20-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NENE 34-28N-113W ORIGINAL WELLS CBU 2-35 PW 00316-30-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SENW 35-28N-113W ORIGINAL WELLS CBU 20-34 PW 00316-40-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NENW 34-28N-113W ORIGINAL WELLS CBU 22-35 PW 00316-60-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SESW 35-28N-113W ORIGINAL WELLS CBU 22-35 PW 00316-60-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SESW 35-28N-113W ORIGINAL WELLS CBU 23-34 PW 00316-70-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SENE 34-28N-113W ORIGINAL WELLS CBU 23-34 PW 00316-70-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SENE 34-28N-113W ORIGINAL WELLS CBU 26-34 PW 00316-90-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E"(F2 ZONE) DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 26-34 PW 00316-90-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 (TGS) OPERATOR: EOG FORMATION: FRONTIER "D-E" (F1 TGS) DESCRIPTION: SESE 34-28N-113W ORIGINAL WELLS CBU 27-34 PW 00317-00-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNE 34-28N-113W ORIGINAL WELLS CBU 27-34 PW 00317-00-00-2 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWNE 34-28N-113W ORIGINAL WELLS CBU 28-23 PW 01970-40-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER "B" DESCRIPTION: 860' FNL & 1780' FWL, SEC 23-28N-113W(NENW) ORIGINAL WELLS CBU 3-34 PW 00317-10-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: NWSE 34-28N-113W ORIGINAL WELLS CBU 36-26 PW 00317-20-00-1 WY SUBLETTE 1.0000000 .8391339 1.0000000 .8391339 OPERATOR: EOG FORMATION: FRONTIER "D-E" DESCRIPTION: SWSE 26-28N-113W ORIGINAL WELLS CBU 36-26 LW 00317-20-00-2 WY SUBLETTE 1.0000000 .8321055 1.0000000 .8321055 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSE 26-28N-113W ORIGINAL WELLS CBU 38-14 LW 01970-50-00-2 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557813 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSW 14-28N-113W ORIGINAL WELLS CBU 38-14 PW 01970-50-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER PA "B" DESCRIPTION: 460' FSL, 460' FWL, SEC 14-28N-113W(SWSW) ORIGINAL WELLS CBU 5-14 PW 00317-40-00-1 WY SUBLETTE .9666666 .8273960 .9666666 .8273960 OPERATOR: EOG FORMATION: FRONTIER "B" DESCRIPTION: NESW 14-28N-113W ORIGINAL WELLS CBU 6-30 LW *00317-50-00-2 WY SUBLETTE 1.0000000 .8355264 1.0000000 .8355264 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 30-28N-112W ORIGINAL WELLS CBU 6-30 PW *00317-50-00-1 WY SUBLETTE 1.0000000 .8355265 1.0000000 .8355265 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 30-28N-112W (NWSE) ORIGINAL WELLS CBU 7-27 PW 00317-70-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENW 27-29N-113W ORIGINAL WELLS CBU 9-26 LW 00317-80-00-1 WY SUBLETTE 1.0000000 .8090191 1.0000000 .8090191 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWNE 26-28N-113W ORIGINAL WELLS CDR CRK 1-3200318-10-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWNE 32-27N-113W ORIGINAL WELLS CDR CRK 12-32 CW 00149-10-00-1 WY SUBLETTE 1.0000000 .8475000 1.0000000 .8475000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 574' FSL & 1223' FEL 32-27N-113W (SESE) ORIGINAL WELLS CDR CRK 2-3300101-30-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SESE 33-27N-113W ORIGINAL WELLS CDR CRK 7-33 LW 00148-90-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (BX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 7-33 LW 00148-90-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (FR) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 7-33 LW 00148-90-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (M) OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 2800' FEL & 630' FNL 33-27N-113W (NENW) ORIGINAL WELLS CDR CRK 8-32 LW 00149-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2250' FNL & 2160' FEL 32-27N-113W (SWNE) ORIGINAL WELLS CH FED 2-17 00321-30-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SENW 17-30N-113W ORIGINAL WELLS CH FED 2-17 (TA)00321-30-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SENW 17-30N-113W ORIGINAL WELLS CH FED 24-08 00321-40-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SESW 8-30N-113W ORIGINAL WELLS CH FED 24-08 (TA)00321-40-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SESW 8-30N-113W ORIGINAL WELLS CHAPEL 10-25 LW *00322-70-00-1 WY SUBLETTE .0000000 .0166900 .0281676 .0235551 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 1312 FNL 1306 FWL CNW-25-28N-112W (LONG ISLAND PROSPECT) ORIGINAL WELLS CHRISMAN 1-10 LW *00327-00-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SENE 10-29N-113W ORIGINAL WELLS CONNELLY A LW 00091-10-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-32 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 32-27N-113W ORIGINAL WELLS CONNELLY A BX 00346-60-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-33 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NWSW 33-27N-113W ORIGINAL WELLS CONNELLY B LW 00346-70-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-33 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CONNELLY B LW 00346-70-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-33 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 636' FNL, 662' FWL 33-27N-113W (NWNW) ORIGINAL WELLS CONNELLY B LW 00346-70-00-4 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-33 OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CONNELLY B M 00346-70-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 1C-33 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NWNW 33-27N-113W ORIGINAL WELLS CUTTHROAT LW 01902-20-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 1-34 OPERATOR: EOG FORMATION: ALMY L ZONE DESCRIPTION: 1320' FEL, 2340' FNL 34-29N-113W S/2NE ORIGINAL WELLS DHU 4-10 PW*00063-50-00-1 WY SUBLETTE 1.0000000 .8327143 1.0000000 .8327143 OPERATOR: EOG FORMATION: ALMY "B" DESCRIPTION: SESW 10-30N-113W ORIGINAL WELLS DPU 1 PW*00747-30-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SWSW 14-27N-114W ORIGINAL WELLS DPU 10 PW*00747-60-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SENE 10-27N-114W ORIGINAL WELLS DPU 11 PW*00747-70-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NWSE 34-28N-114W ORIGINAL WELLS DPU 13 PW*00747-80-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: SWNE 14-27N-114W ORIGINAL WELLS DPU 14 PW*00747-90-00-1 WY SUBLETTE .4074307 .3519728 .4074307 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NESE 4-27N-114W ORIGINAL WELLS DPU 22 FR PW*00749-10-00-1 WY SUBLETTE .3149122 .2692553 .3149122 .2692553 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER A DESCRIPTION: NWNW 24-27N-114W ORIGINAL WELLS DPU 23 PW*00749-20-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: NWSE 4-27N-114W ORIGINAL WELLS DPU 23 PW*00749-30-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: NWSE 4-27N-114W ORIGINAL WELLS DPU 26 PW*00749-80-00-1 WY SUBLETTE .2500000 .2165625 .2500000 .2165625 OPERATOR: WEXPRO COMPANYFORMATION: NUGGET DESCRIPTION: NESW 10-27N-114W ORIGINAL WELLS DPU 3 PW*00750-00-00-1 WY SUBLETTE .4074307 .3519728 .4074307 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: SWSW 4-27N-114W ORIGINAL WELLS DPU 6 FR PW*00750-70-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: SWNE 36-28N-114W ORIGINAL WELLS DPU 8 P/A*00750-80-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: SESE 35-28N-114W ORIGINAL WELLS DPU 9 PW*00751-00-00-1 WY SUBLETTE .4074307 .3519728 .4074320 .3519728 OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER B-C DESCRIPTION: NESE 3-27N-114W ORIGINAL WELLS DRY BASIN 1-8 CW*00158-30-00-1 WY SUBLETTE 1.0000000 .8400000 1.0000000 .8400000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1222' FSL & 1027' FWL, SEC 8-28N-113W(SWSW) ORIGINAL WELLS DRY PINEY-BR A*99999-99-99-T WY SUBLETTE .2500000 .2165620 .2500000 .2165620 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: BEAR RIVER PA "A" ORIGINAL WELLS DRY PINEY-BR B*99999-99-99-U WY SUBLETTE .2500000 .2165620 .2500000 .2165620 OPERATOR: WEXPRO COMPANYFORMATION: BEAR RIVER DESCRIPTION: BEAR RIVER PA "B" ORIGINAL WELLS DRY PINEY- A*99999-99-99-V WY SUBLETTE .2500000 .2165620 .2500000 .2165620 DAKOTA OPERATOR: WEXPRO COMPANYFORMATION: DAKOTA DESCRIPTION: DAKOTA PA "A" ORIGINAL WELLS DRY PINEY- B-C*99999-99-99-S WY SUBLETTE .3089990 .2671000 .3089990 .2671000 FRONT OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: CONSL. FRONTIER PA "B-C" ORIGINAL WELLS DRY PINEY- A*99999-99-99-R WY SUBLETTE .2412290 .2071550 .2412290 .2071550 FRONTIER OPERATOR: WEXPRO COMPANYFORMATION: FRONTIER DESCRIPTION: FRONTIER PA "A" ORIGINAL WELLS DRY PINEY- *99999-99-99-E WY SUBLETTE .2500000 .2165625 .2500000 .2165625 NUGGET OPERATOR: WEXPRO COMPANYFORMATION: NUGGET DESCRIPTION: NUGGET PA "A" ORIGINAL WELLS E 22-31 LW*00069-10-00-1 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557813 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 31-28N-112W ORIGINAL WELLS ELB R 1-29 PW*00768-30-00-1 WY SUBLETTE .8125000 .7034374 .8125000 .7034374 OPERATOR: EOG FORMATION: ALMY R-1 DESCRIPTION: 29-27N-112W, NESE ORIGINAL WELLS ELB R 7-32 LW*00768-50-00-1 WY SUBLETTE .8125000 .6562510 .8125000 .6562510 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 32-27N-112W, NWNE ORIGINAL WELLS ELB R 8-29 PW*00768-60-00-1 WY SUBLETTE .7500000 .6562510 .7500000 .6562510 OPERATOR: EOG FORMATION: ALMY R-8 DESCRIPTION: 29-27N-112W, LOT 7(NWSE) ORIGINAL WELLS ELB R 9-29 LW*00768-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 29-27N-112W, SWNE ORIGINAL WELLS ELB 1-33 PW 00768-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 33-27N-112W ORIGINAL WELLS ELB 12-27 LW 00769-20-00-1 WY SUBLETTE .5000000 .4180850 .5000000 .4180850 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 27-27N-112W ORIGINAL WELLS ELB 15-29 PW 00769-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 29-27N-112W ORIGINAL WELLS ELB 17-33 PW 00769-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 33-27N-112W ORIGINAL WELLS ELB 19-28 PW 00769-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSW 28-27N-112W ORIGINAL WELLS ELB 2A-33 PW 00770-10-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENW 33-27N-112W ORIGINAL WELLS ELB 20-21 PW 00770-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 21-27N-112W ORIGINAL WELLS ELB 21-29 PW 00770-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 29-27N-112W ORIGINAL WELLS ELB 22-32 PW 00770-60-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 32-27N-112W ORIGINAL WELLS ELB 25-32 PW 00770-90-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 32-27N-112W ORIGINAL WELLS ELB 27-32 PW 00771-10-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 27-27N-112W ORIGINAL WELLS ELB 29-28 PW 00771-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESE 28-27N-112W ORIGINAL WELLS ELB 30-21 PW 00771-40-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: LOT 8 21-27N-112W ORIGINAL WELLS ELB 31-21 PW 02147-40-00-1 WY SUBLETTE .5137380 .4433424 .5137380 .4433424 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 630' FNL, 825' FEL 21-27N-112W NENE ORIGINAL WELLS ELB 32-33 PW 00771-60-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 33-27N-112W ORIGINAL WELLS ELB 33-28 PW 00771-70-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 28-27N-112W ORIGINAL WELLS ELB 40-32 PW *00772-50-00-1 WY SUBLETTE .4533659 .3940400 .4533659 .3940400 OPERATOR: EOG FORMATION: MESA "A" DESCRIPTION: 32-27N-112W, SWNE ORIGINAL WELLS ELB 41-28 PW 00151-70-00-1 WY SUBLETTE 1.0000000 .8656687 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 28-27N-112W ORIGINAL WELLS ELB 5-28 PW 00773-00-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNE 28-27N-112W ORIGINAL WELLS ELB 68-22 PW 00164-50-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SWSW 22-27N-112W ORIGINAL WELLS ELB 7-29 PW 00773-20-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 29-27N-112W ORIGINAL WELLS ELB 8-32 PW 00773-30-00-1 WY SUBLETTE .5137380 .4443563 .5137380 .4443563 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NESW 32-27N-112W ORIGINAL WELLS FEDERAL 10-29 LW *00111-90-00-1 WY SUBLETTE .3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: 1320 FNL 1320 FWL (NW-29-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL30-15 CW *00110-40-00-1 WY SUBLETTE .3181080 .2477266 .2544864 .2045886 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER DESCRIPTION: SW-15-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-05 LW *00109-80-00-1 WY SUBLETTE .3181080 .2521005 .2193040 .1693282 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW 5-27N-111W ORIGINAL WELLS FEDERAL 10-17 LW *00110-50-00-1 WY SUBLETTE .3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-17-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-19 LW*00111-10-00-1 WY SUBLETTE .2125000 .1710620 .2125000 .1710620 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-19-27N-111W ORIGINAL WELLS FEDERAL 10-20 LW*00111-20-00-1 WY SUBLETTE .1130950 .0910415 .1130950 .0910415 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-20-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-28 LW*00111-70-00-1 WY SUBLETTE .2907640 .2151653 .2907640 .2151653 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-28-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-30 CW*00112-20-00-1 WY SUBLETTE .2125000 .1722387 .2125000 .1722387 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-30-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-31 LW*00791-50-00-1 WY SUBLETTE .2491698 .1963644 .1789269 .1440362 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 938 FWL 1320 FNL (W2NW-31-28N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 10-32 LW*00112-40-00-1 WY SUBLETTE .2293561 .1697236 .2293561 .1697236 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SENW-32-27N-11W ORIGINAL WELLS FEDERAL 10-8 *00110-20-00-1 WY SUBLETTE .2226760 .1781410 .2226760 .1781410 (LW) OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW-8-27N-111W (W2) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-07 LW*00110-00-00-1 WY SUBLETTE .2544864 .2083607 .2544864 .2083607 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NE 7-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-17 LW*00110-60-00-1 WY SUBLETTE .1908648 .1517375 .1908648 .1517375 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: NWNE 17-27N-111W (NE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-20 LW*00111-30-00-1 WY SUBLETTE .0954478 .0768349 .0954478 .0768349 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: E2-20-27N-111W (NE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 20-29 CW*00112-00-00-1 WY SUBLETTE .3101554 .2512656 .3101554 .2512656 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: 1120 FNL 1520 FEL (SE-29-27N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-08 CW*00110-30-00-1 WY SUBLETTE .2226760 .1765502 .2226760 .1765502 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-8-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-17 LW*00110-70-00-1 WY SUBLETTE .3181080 .2560769 .3181080 .2560769 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-17-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-20 CW*00111-40-00-1 WY SUBLETTE .0343370 .0300043 .0343370 .0300043 OPERATOR: PRESIDIO OIL COMPANYFORMATION: BEAR RIVER DESCRIPTION: 1120 FSL 1120 FWL (SWSW-20-27N-111W) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-28 CW*00119-70-00-1 WY SUBLETTE .2907640 .2151655 .2907640 .2151655 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: SW-28-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 30-31 LW*00109-70-00-1 WY SUBLETTE .0704190 .0566873 .0704190 .0566873 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SW-31-28N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-06 *00109-90-00-1 WY SUBLETTE .2226760 .1781408 .2226760 .1781408 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE 6-27N-111W ORIGINAL WELLS FEDERAL 40-07 LW*00110-10-00-1 WY SUBLETTE .0000000 .0000000 .2544864 .1937274 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE 7-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-17 LW*01932-00-00-1 WY SUBLETTE .0473856 .0381454 .0473856 .0381454 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-17-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-20 LW*00111-50-00-1 WY SUBLETTE .0771502 .0607558 .0771502 .0607558 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: E2-20-27N-111W (SE) (BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-29 CW*00112-10-00-1 WY SUBLETTE .3101554 .2512656 .3101554 .2512656 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER/BEAR RIVER DESCRIPTION: 1320 FEL 1320 FSL (SE-29-27N-111W(BIRD CANYON PROSPECT) ORIGINAL WELLS FEDERAL 40-30 LW*00112-30-00-1 WY SUBLETTE .2125000 .1710625 .2125000 .1710625 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-30-27N-111W ORIGINAL WELLS FEDERAL 40-32 LW*00112-50-00-1 WY SUBLETTE .3181080 .2560768 .3181080 .2560768 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: SE-32-27N-111W (BIRD CANYON PROSPECT) ORIGINAL WELLS FFC 1-01 LW&*00798-30-00-1 WY SUBLETTE .8750000 .7000000 .6125000 .5236875 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESE 1-27N-112W ORIGINAL WELLS FFC 1-15 PW 00797-70-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: 1650' FSL, 1650' FWL 15-27N-112W NESW ORIGINAL WELLS FFC 10-15 PW 00797-80-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: 2070' FEL, 2125' FNL 15-27N-112W SWNE ORIGINAL WELLS FFC 11-14 LW*00797-90-00-1 WY SUBLETTE 1.0000000 .7474281 1.0000000 .7474281 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: C NW 14-27N-112W ORIGINAL WELLS FFC 13-10 PW 01970-30-00-1 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 813' FSL, 2170' FEL 10-27N-112W SWSE ORIGINAL WELLS FFC 2-12 CW 00798-00-00-1 WY SUBLETTE .8062500 .6843437 .8062500 .6843437 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENE 12-27N-112W ORIGINAL WELLS FFC 2-12 CW 00798-50-00-1 WY SUBLETTE .9000000 .7645000 .9000000 .7645000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SENE 12-27N-112W ORIGINAL WELLS FFC 3-12 LW00798-60-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 3-12 LW00798-60-00-2 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 3-12 (TGS)LW00798-60-00-3 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER (TGS) DESCRIPTION: 1300' FSL, 500' FEL 12-27N-112W SESE ORIGINAL WELLS FFC 4-13 LW 00798-70-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NENE 13-27N-112W ORIGINAL WELLS FFC 5-13 LW00798-80-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: NESE 13-27N-112W ORIGINAL WELLS FFC 6-31 LW00798-90-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: SWNE 31-28N-111W ORIGINAL WELLS FFC 7-31 (BR) CW00799-00-00-1 WY SUBLETTE .0000000 .0000000 .6644060 .5448468 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: 1320' FSL, 519' FEL 31-28N-111W NWSE ORIGINAL WELLS FFC 8-30 LW00799-10-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER DESCRIPTION: NESW 30-28N-111W ORIGINAL WELLS FFCU 2-10 PW&*00798-00-00-2 WY SUBLETTE 1.0000000 .8573513 1.0000000 .8573513 OPERATOR: EOG FORMATION: FRONTIER/BEAR RIVER MUDDY DESCRIPTION: SESW 10-27N-112W ORIGINAL WELLS FFF 1-1 LW 00798-30-00-2 WY SUBLETTE .8750000 .7000000 .6125000 .5236875 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 1-27N-112W ORIGINAL WELLS FFF 7-31 CW 00799-00-00-2 WY SUBLETTE .0000000 .0000000 .6644060 .5448468 (FRONT) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1320' FSL, 519' FEL 31-28N-111W NESE ORIGINAL WELLS FOG CRK 1-08 PW*00910-40-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SESW 8-28N-114W ORIGINAL WELLS FOG CRK 1-32 PW*00910-30-00-1 WY SUBLETTE .1145950 .0977064 .1145950 .0977064 OPERATOR: EXXON CO USAFORMATION: FRONTIER A DESCRIPTION: LOT 19 32-28N-114W ORIGINAL WELLS FOG CRK 10-08 LW*00910-50-00-1 WY SUBLETTE .1250000 .0990168 .1250000 .0990168 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: NENW 8-28N-113W (FOGARY CREEK PROSPECT) ORIGINAL WELLS FOG CRK 2-16 PW*00910-80-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SWNW 16-28N-114W ORIGINAL WELLS FOG CRK 3-04 LW*00910-90-00-1 WY SUBLETTE .2500000 .1950000 .1250000 .0990168 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: LOT 18 4-28N-114W ORIGINAL WELLS FOG CRK 4-17 PW*00911-00-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER B DESCRIPTION: SWSE 17-28N-114W ORIGINAL WELLS FOG CRK 6-16 PW*00911-10-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: SWSE 16-28N-114W ORIGINAL WELLS FOG CRK 7-09 LW*00911-20-00-1 WY SUBLETTE .6875000 .5128719 .3437500 .2774553 OPERATOR: EXXON CO USAFORMATION: FRONTIER DESCRIPTION: SWSE 9-28N-114W (W2SE4) ORIGINAL WELLS FOG CRK 8-20 PW*00911-30-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: NESE 20-28N-114W ORIGINAL WELLS FOG CRK 9-21 PW*00911-40-00-1 WY SUBLETTE .2168523 .1764244 .2168523 .1764244 OPERATOR: EXXON CO USAFORMATION: FRONTIER "B" DESCRIPTION: NESW 21-28N-114W ORIGINAL WELLS GHU 3-32 PW*00939-80-00-1 WY SUBLETTE .5000000 .4275042 .5000000 .4275042 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNW 32-31N-113W ORIGINAL WELLS GHU 5-32 PW*00939-90-00-1 WY SUBLETTE .5000000 .4275042 .5000000 .4275042 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 32-31N-113W ORIGINAL WELLS GRB B 18-19 PW 02173-00-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: LOT 4, (SWSW), 19-27N-112W, 750' FSL & 560' FWL ORIGINAL WELLS GRB B 2-36 PW 00158-20-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 BAXTER OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 580' FNL & 2650' FEL (NWNE), 36-27N-113W ORIGINAL WELLS GRB B 4-36 PW 01975-30-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1900' FWL & 1700' FSL (NESW), 36,27N,113W ORIGINAL WELLS GRB B 5-36 PW 01975-40-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 BAX OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1370' FSL & 1279' FEL, NESE, 36: 27N-113W ORIGINAL WELLS GRB B 6-1 PW 01975-50-00-1 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 518' FNL & 1467' FEL, LOT 37, 1-26N-113W ORIGINAL WELLS GRB T 14-34 PW*00946-10-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4493539 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 34-27N-113W, NENE ORIGINAL WELLS GRB T 15-27 PW*00946-20-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NWNE ORIGINAL WELLS GRB T 16A-27 PW*00946-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SWNE ORIGINAL WELLS GRB T 17-27 PW*00946-40-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NENE ORIGINAL WELLS GRB T 18-27 PW*00946-50-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SENE ORIGINAL WELLS GRB T 24-27 PW*00947-10-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, NESE ORIGINAL WELLS GRB T 26-35 PW*00947-20-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SWNW ORIGINAL WELLS GRB T 27-35 PW*00947-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV "A-B-C" DESCRIPTION: 35-27N-113W (NWNW) ORIGINAL WELLS GRB T 28-35 PW*00947-60-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NWSW ORIGINAL WELLS GRB T 29-35 PW*00947-70-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NENW ORIGINAL WELLS GRB T 32-27 PW*00947-90-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 27-27N-113W, SESE ORIGINAL WELLS GRB T 36-35 PW*00948-30-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SENW ORIGINAL WELLS GRB T 37-35 PW*00948-40-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, NESW ORIGINAL WELLS GRB T 39-35 *00948-50-00-1 WY SUBLETTE .0000000 .0000000 .5235390 .4491970 OPERATOR: EOG FORMATION: MESV A-B-C DESCRIPTION: 35-27N-113W, SWSW ORIGINAL WELLS GRB T 44-31 PW*00948-90-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY T-41 DESCRIPTION: NESW 31-27N-112W ORIGINAL WELLS GRB T 60-34 PW*00949-90-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, SENE ORIGINAL WELLS GRB T 61-34 PW*00950-00-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, NESE ORIGINAL WELLS GRB T 62-34 PW*00950-10-00-1 WY SUBLETTE .5235390 .4491970 .5235390 .4491970 OPERATOR: EOG FORMATION: MESAVERDE A-B-C DESCRIPTION: 34-27N-113W, SESE ORIGINAL WELLS GRB T 8-36 PW*00951-10-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: ALMY T-5 DESCRIPTION: 36-27N-113W, NESW ORIGINAL WELLS GRB 1-19 PW 00951-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 19-27N-112W ORIGINAL WELLS GRB 10-09 PW 00951-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 9-27N-112W ORIGINAL WELLS GRB 100-35 PW 00952-00-00-1 WY SUBLETTE .9190310 .7785252 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B (ZONE 2) DESCRIPTION: SEC. 35-27N-113W, (NWNW) ORIGINAL WELLS GRB 100-35 PW 00952-00-00-2 WY SUBLETTE .9190310 .7785252 .9198070 .7792040 (TGS) OPERATOR: EOG FORMATION: FRONTIER A-B (ZONE 1/TGS) DESCRIPTION: SEC. 35-27N-113W, (NWNW) ORIGINAL WELLS GRB 102-36 BR PW 00159-50-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 560' FNL & 2700' FEL {NWNE}, SEC 36-27N-113W ORIGINAL WELLS GRB 102-36 F PW 00159-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 560' FNL & 2700' FEL {NWNE} SEC 36-27N-113W ORIGINAL WELLS GRB 13-17 PW 00952-20-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 17-27N-112W ORIGINAL WELLS GRB 14-20 PW 00952-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 20-27N-112W ORIGINAL WELLS GRB 15-07 PW 00952-40-00-1 WY SUBLETTE 1.0000000 .8453506 1.0000000 .8453506 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: NENW 7-27N-112W ORIGINAL WELLS GRB 152-11 PW 00158-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 2391' FEL & 2615' FNL, SEC. 11-26N-113W, (SWNE) ORIGINAL WELLS GRB 16-33 LW 00952-50-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 33-28N-112W ORIGINAL WELLS GRB 19-35 BR PW 00952-90-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSE 35-27N-113W ORIGINAL WELLS GRB 19-35 F PW 00952-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSE 35-27N-113W ORIGINAL WELLS GRB 21-34 F PW 00953-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 34-27N-113W ORIGINAL WELLS GRB 21-34 M PW 00953-40-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 34-27N-113W ORIGINAL WELLS GRB 22-27 BR PW 00953-50-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNE 27-27N-113W ORIGINAL WELLS GRB 22-27 F PW 00953-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 27-27N-113W ORIGINAL WELLS GRB 28-18 PW 00954-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 18-27N-112W ORIGINAL WELLS GRB 29-30 PW 00954-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 30-27N-112W ORIGINAL WELLS GRB 29-30 PW 00954-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 500' FNL & 1320' FWL, NENW 30-27N-112W ORIGINAL WELLS GRB 3-31 PW 00954-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSE 31-27N-112W ORIGINAL WELLS GRB 33-06 PW 00954-50-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SWSE 6-27N-112W ORIGINAL WELLS GRB 35-07 PW 00954-70-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SESE 7-27N-112W ORIGINAL WELLS GRB 36-18 PW 00954-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 18-27N-112W ORIGINAL WELLS GRB 37-20 PW 00954-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 20-27N-112W ORIGINAL WELLS GRB 38-36 PW 00955-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1345' FNL & 500' FELSENE 36-27N-113W ORIGINAL WELLS GRB 38-36 PW 00955-00-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1345' FNL500' FEL, SENE, 36-27N-113W ORIGINAL WELLS GRB 39A-31 PW 00955-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1600' FNL & 1600' FWL, SEC. 31-27N-112W, (SENW) ORIGINAL WELLS GRB 39A-31 PW 00955-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1600' FNL & 1600' FWL, SEC. 31-27N-112W, (SENW) ORIGINAL WELLS GRB 41-36 BRPW00955-40-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNW 36-27N-113W ORIGINAL WELLS GRB 41-36 F PW 00955-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 36-27N-113W ORIGINAL WELLS GRB 46A-1 PW 00955-90-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 5262' FNL & 963' FEL, LOT 37, 1-26N-113W ORIGINAL WELLS GRB 49-19 PW 00956-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 19-27N-113W ORIGINAL WELLS GRB 49-19 PW 00956-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 BAXTER OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SESE 19-27N-113W ORIGINAL WELLS GRB 50-30 PW 00956-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 30-27N-112W ORIGINAL WELLS GRB 50-30 PW 00956-30-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SENE 30-27N-112W ORIGINAL WELLS GRB 52-35 BRPW00956-50-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NWSW 35-27N-113W ORIGINAL WELLS GRB 52-35 F PW 00956-50-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWSW 35-27N-113W ORIGINAL WELLS GRB 54-36 F PW 00956-70-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSW 36-27N-113W ORIGINAL WELLS GRB 54-36 M PW 00956-70-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWSW 36-27N-113W ORIGINAL WELLS GRB 57-06 PW 00056-90-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENE 6-27N-112W ORIGINAL WELLS GRB 59-7 PW 00957-10-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SWNE 7-27N-112W ORIGINAL WELLS GRB 6-30 PW 00957-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWSE 30-27N-112W ORIGINAL WELLS GRB 6-30 PW 00957-30-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SWSE 30-27N-112W ORIGINAL WELLS GRB 60-17 PW 00957-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESW 17-27N-112W ORIGINAL WELLS GRB 63-35 BR PW 00957-70-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SENE 35-27N-113W ORIGINAL WELLS GRB 63-35 F PW 00957-70-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENE 35-27N-113W ORIGINAL WELLS GRB 66-17 PW 00958-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 17-27N-112W ORIGINAL WELLS GRB 67-06 PW 00958-20-00-1 WY SUBLETTE 1.0000000 .8453531 1.0000000 .8453531 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: NESW 6-27N-112W ORIGINAL WELLS GRB 68-30 PW 00958-30-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 30-27N-113W ORIGINAL WELLS GRB 68-30 PW 00958-30-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESW 30-27N-113W, 1500' FWL & 2150' FSL ORIGINAL WELLS GRB 69-19 PW 00958-40-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENW 19-27N-112W ORIGINAL WELLS GRB 69-19 PW 00958-40-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1300' FNL & 1650' FWL NENW 19-27N-112W ORIGINAL WELLS GRB 7-06 PW 00958-50-00-1 WY SUBLETTE 1.0000000 .8453530 1.0000000 .8453530 OPERATOR: EOG FORMATION: FRONTIER "C" DESCRIPTION: SENW 6-27N-112W ORIGINAL WELLS GRB 70-19 PW 00958-60-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESW 19-27N-112W ORIGINAL WELLS GRB 70-19 PW 00958-60-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NESW 19-27N-112W ORIGINAL WELLS GRB 72-27 BR PW 00958-80-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: 1407' FEL & 2532' FSL, SEC. 27-27N-113W, (NWSE) ORIGINAL WELLS GRB 72-27 F PW 00958-80-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 1407' FEL & 2532' FSL, SEC. 27-27N-113W, (NWSE) ORIGINAL WELLS GRB 73-17 F PW 00958-90-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNW 17-27N-112W ORIGINAL WELLS GRB 74-31 PW 00959-00-00-3 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1000' FWL & 1350' FSL, E2SW, 31-27N-112W ORIGINAL WELLS GRB 74-31 F PW 00959-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: E2SW 31-27N-112W ORIGINAL WELLS GRB 74-31 M PW 00959-00-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: E2SW 31-27N-112W ORIGINAL WELLS GRB 75-31 PW 00959-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: E NE 31-27N-112W ORIGINAL WELLS GRB 75-31 PW 00959-10-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547653 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: NENE 31-27N-112W ORIGINAL WELLS GRB 8-36 BR PW 00959-60-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NESE, 36-27N-113W ORIGINAL WELLS GRB 8-36 F PW 00959-60-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NESE 36-27N-113W ORIGINAL WELLS GRB 81-36 BR PW 00959-80-00-2 WY SUBLETTE 1.0000000 .8509818 .8289570 .7060031 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: SWNE 36-27N-113W ORIGINAL WELLS GRB 81-36 F PW 00959-80-00-1 WY SUBLETTE 1.0000000 .8358373 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SWNE 36-27N-113W ORIGINAL WELLS GRB 82-6 PW 00959-90-00-2 WY SUBLETTE 1.0000000 .8547652 1.0000000 .8547652 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 800' FWL & 2200' FNL, SENW, 6-26N-112W ORIGINAL WELLS GRB 88-35 PW 00960-60-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SENW 35-27N-113W ORIGINAL WELLS GRB 90-34 PW 00152-00-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: 480' FEL & 2358' FNL {SENE} SECTION 34, T27N, R113W ORIGINAL WELLS GRB 94-27 F PW 00961-40-00-1 WY SUBLETTE .9190310 .7670147 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: SESE 27-27N-113W ORIGINAL WELLS GRB 98-27 PW 00152-10-00-3 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 98-27 PW 00152-10-00-2 WY SUBLETTE .8289570 .7060032 .8289570 .7060032 BR/MUD OPERATOR: EOG FORMATION: BEAR RIVER/85% ALLOCATION DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 98-27 PW 00152-10-00-1 WY SUBLETTE .9198070 .7792040 .9198070 .7792040 FR 2 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: 788' FNL & 2849' FWL {NWNE}, SECTION 27, T27N-R113W ORIGINAL WELLS GRB 99-27 BR PW 00961-60-00-2 WY SUBLETTE .7906803 .6805900 .8289570 .7060032 OPERATOR: EOG FORMATION: BEAR RIVER MUDDY DESCRIPTION: NENE 27-27N-113W ORIGINAL WELLS GRB 99-27 F PW 00961-60-00-1 WY SUBLETTE .9190310 .7670147 .9198070 .7792040 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NENE 27-27N-113W ORIGINAL WELLS GULF STATE LW *00964-90-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 1-16 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-112W, (SESW) ORIGINAL WELLS HAIRSEAR 1-22 LW 01902-40-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY K SAND DESCRIPTION: 690' FEL & 1730' FNL, SEC. 22-29N-113W, (SENE) ORIGINAL WELLS HORSESHOE 00113-00-00-1 WY SUBLETTE 1.0000000 .8750000 .5000000 .4375000 BEND 1-20 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NENE 20-27N-112W ORIGINAL WELLS HORSESHOE 00113-10-00-1 WY SUBLETTE 1.0000000 .8750000 .5000000 .4375000 BEND 2-21 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWNW 21-27N-112W ORIGINAL WELLS ISE 16-17 PW *00662-90-00-1 WY SUBLETTE .4502007 .3790573 .4502007 .3790573 (P&A) OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 2530' FEL & 2180' FSL, 17-29N-112W(NWSE) ORIGINAL WELLS ISENHOUR-ALMY *99999-99-99-F WY SUBLETTE .4502000 .3790457 .4502000 .3790457 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY PA ORIGINAL WELLS JORY HILL CW 01990-80-00-2 WY SUBLETTE .5000000 .4068750 .5000000 .4068750 1-29 (M) OPERATOR: EOG FORMATION: MUDDY 16% ALLOCATION DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W (SENE) ORIGINAL WELLS JORY HILL CW 01990-80-00-1 WY SUBLETTE .5000000 .4068750 .5000000 .4068750 1-29 FR OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W, (SENE) ORIGINAL WELLS JORY HILL CW 01990-80-00-4 WY SUBLETTE .5000000 .4068750 .5000000 .4068750 1-29 FR OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: 2240' FNL & 1104' FEL, SEC. 29-27N-113W, (SENE) ORIGINAL WELLS LIU 3-24 PW*01045-70-00-1 WY SUBLETTE 1.0000000 .7949999 1.0000000 .7949999 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: SWSW 24-29N-112W ORIGINAL WELLS LIU 4-23 PW*01046-30-00-1 WY SUBLETTE 1.0000000 .7499999 1.0000000 .7949999 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NESE 23-29N-112W ORIGINAL WELLS LONG ISLAND *99999-99-99-D WY SUBLETTE 1.0000000 .8250688 1.0000000 .8250688 ALMY A-B OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY PA A-B ORIGINAL WELLS LONG ISLAND *99999-99-99-C WY SUBLETTE 1.0000000 .7950000 1.0000000 .7950000 MESV OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: MESAVERDE PA ORIGINAL WELLS M & M 1-14 LW&*01601-60-00-1 WY SUBLETTE 1.0000000 .8150000 1.0000000 .8150000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNW 14-29N-113W ORIGINAL WELLS MASON 3-18 LW *01615-50-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSW 18-31N-113W ORIGINAL WELLS MCD ALMY PA A*99999-99-99-G WY SUBLETTE 1.0000000 .8532585 1.0000000 .8532585 OPERATOR: EOG FORMATION: ALMY A DESCRIPTION: ALMY PA A ORIGINAL WELLS MCD ALMY *99999-99-99-H WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 PA B-F OPERATOR: EOG FORMATION: ALMY B-F DESCRIPTION: ALMY PA B-F ORIGINAL WELLS MCD ALMY *99999-99-99-I WY SUBLETTE 1.0000000 .8446556 1.0000000 .8446556 PA C-D OPERATOR: EOG FORMATION: ALMY C-D DESCRIPTION: ALMY PA C-D ORIGINAL WELLS MCD ALMY PA E*99999-99-99-J WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: ALMY E DESCRIPTION: ALMY PA E ORIGINAL WELLS MCD ALMY PA H*99999-99-99-K WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY H DESCRIPTION: ALMY PA H ORIGINAL WELLS MCD ALMY PA I*99999-99-99-L WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: ALMY I DESCRIPTION: ALMY PA I ORIGINAL WELLS MCD ALMY PA J*99999-99-99-M WY SUBLETTE .5000000 .4225000 .5000000 .4225000 OPERATOR: EOG FORMATION: ALMY J DESCRIPTION: ALMY PA J ORIGINAL WELLS MCD 87-18 PW&*00435-00-00-1 WY SUBLETTE .5000000 .4225000 .5000000 .4225000 OPERATOR: EOG FORMATION: ALMY J DESCRIPTION: NENE 18-28N-112W ORIGINAL WELLS MICK CRK FED LW *01078-80-00-1 WY SUBLETTE .7000000 .5792500 .7000000 .5792500 1-17 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NWNW 17-32N-114W660' FNL & 460' FWL ORIGINAL WELLS MILLS 1-22 LW00442-60-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS MILLS 1-22 LW 00442-60-00-2 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SESE 22-28N-113W ORIGINAL WELLS MILLS 2-23 LW&*00442-70-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 23-27N-113W, SWSW ORIGINAL WELLS MP 10-3 LW00150-00-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 718' FSL & 280' FEL, SEC. 3-29N-113W, (SESE) ORIGINAL WELLS MP 12-1 001079-40-00-1 WY SUBLETTE 1.0000000 .8101500 1.0000000 .8101500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENE 10-29N-113W ORIGINAL WELLS MP 14-1 101079-50-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWNW 11-29N-113W ORIGINAL WELLS MP 16-10 LW 01079-60-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 460' FEL, & 2060' FSL, SEC. 10-29N-113W, (NESE) ORIGINAL WELLS MP 17-11 LW 01079-70-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 661' FWL, & 2800' FSL, SEC. 11-29N-113W, (NWSW) ORIGINAL WELLS MP 19-10 LW 01079-80-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 792' FSL, & 460' FEL, SEC. 10-29N-113W, (SESE) ORIGINAL WELLS MP 20-11 LW01079-90-00-1 WY SUBLETTE 1.0000000 .8125000 1.0000000 .8125000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 800' FSL, & 861' FWL, SEC. 11-29N-113W, (SWSW) ORIGINAL WELLS MP 21-11 LW00149-80-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 710' FSL & 1980' FWL, SEC. 11-29N-113W, (SESW) ORIGINAL WELLS MP 23-14 01080-00-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW 14-29N-113W ORIGINAL WELLS MP 3-03 01079-10-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NESE 03-29N-113W ORIGINAL WELLS MP 4-11 01079-20-00-1 WY SUBLETTE 1.0000000 .8600000 1.0000000 .8600000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWNW 11-29N-113W ORIGINAL WELLS MP 5-3 LW00150-20-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2022' FNL & 461' FEL, SEC. 3-29N-113W, (SENE) ORIGINAL WELLS MP 7-3 LW00150-10-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2029' FSL & 1830' FEL, SEC. 3-29N-113W, (NWSE) ORIGINAL WELLS MP 9-03 LW01080-10-00-1 WY SUBLETTE 1.0000000 .8137500 1.0000000 .8137500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SWSE 03-29N-113W ORIGINAL WELLS NCB 1-23 00315-20-00-1 WY SUBLETTE 1.0000000 .8557813 1.0000000 .8557812 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SENW 23-28N-113W ORIGINAL WELLS NCB 2-23 CW 01094-10-00-1 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 1331'FEL & 2098' FSL, SEC. 23-28N-113W, (TR 45) ORIGINAL WELLS NCB 2-23 CW 01094-10-00-2 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1331'FEL & 2098' FSL, SEC. 23-28N-113W, (TR 45) ORIGINAL WELLS NCB 4-23 CW 01989-10-00-1 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 600'FSL & 1100'FEL, SEC. 23-28N-113W, (L0T 7) ORIGINAL WELLS NCB 4-23 CW 01989-10-00-2 WY SUBLETTE 1.0000000 .7895050 1.0000000 .7895050 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 600'FSL & 1100'FEL, SEC. 23-28N-113W, (LOT 7) ORIGINAL WELLS NEW FORK MESA *00157-90-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 1-15 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1169' FSL & 1122' FEL, SEC. 15-28N-113W, (SESE) ORIGINAL WELLS NLB 19-09 PW 00463-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, SENW ORIGINAL WELLS NLB 20-08 PW 00463-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, SWNE ORIGINAL WELLS NLB 21-04 PW 00463-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER ORIGINAL WELLS NLB 22-17 PW 00464-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, NESE ORIGINAL WELLS NLB 23-16 PW 00464-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, SESW ORIGINAL WELLS NLB 24-33 PW 00464-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, SWNW ORIGINAL WELLS NLB 25-05 PW 00464-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 5-27N-113W, NWSE ORIGINAL WELLS NLB 26-09 PW 00464-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWSW ORIGINAL WELLS NLB 27-17 PW 00464-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NENW ORIGINAL WELLS NLB 27-17 PW 00464-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NENW ORIGINAL WELLS NLB 30-16 PW 00464-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 16-27N-113W, NESE ORIGINAL WELLS NLB 30-16 PW 00464-90-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 16-27N-113W, NESE ORIGINAL WELLS NLB 31-08 PW 00465-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 8-27N-113W, NWSW ORIGINAL WELLS NLB 32-05 PW 00465-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWSW5-27N-113W ORIGINAL WELLS NLB 32-05 PW 00465-10-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWSW5-27N-113W ORIGINAL WELLS NLB 33-17 PW 00465-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NESW ORIGINAL WELLS NLB 33-17 PW 00465-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NESW ORIGINAL WELLS NLB 34-21 PW 00465-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 21-27N-113W, NWNW ORIGINAL WELLS NLB 34-21 PW 00465-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 21-27N-113W, NWNW ORIGINAL WELLS NLB 35-34 PW 00465-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 34-28N-13W, SWNW ORIGINAL WELLS NLB 35-34 PW 00465-40-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 34-28N-13W, SWNW ORIGINAL WELLS NLB 36-33 PW 00465-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS NLB 36-33 PW 00465-50-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 33-28N-113W, SWNE ORIGINAL WELLS NLB 37-05 PW 00465-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 5-27N-113W, SWSE2153' FEL & 84' FSL ORIGINAL WELLS NLB 37-05 PW 00465-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 5-27N-113W, SWSE2153' FEL & 84' FSL ORIGINAL WELLS NLB 38-08 PW 00465-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 8-27N-113W, NWNW ORIGINAL WELLS NLB 38-08 PW 00465-70-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 8-27N-113W, NWNW ORIGINAL WELLS NLB 39-17 PW 00465-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, NENE ORIGINAL WELLS NLB 39-17 PW 00465-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, NENE ORIGINAL WELLS NLB 40-33 PW 00157-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, NENE ORIGINAL WELLS NLB 40-33 PW 00157-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 33-28N-113W, NENE ORIGINAL WELLS NLB 43-05 PW 00466-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SWNE 5-27N-113W ORIGINAL WELLS NLB 43-05 PW 00466-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SWNE 5-27N-113W ORIGINAL WELLS NLB 44-34 PW 00466-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 34-28N-113W, SWSW ORIGINAL WELLS NLB 44-34 PW 00466-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 34-28N-113W, SWSW ORIGINAL WELLS NLB 45-33 PW 00466-40-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 33-28N-113W, LOT 3 ORIGINAL WELLS NLB 45-33 PW 00466-40-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 33-28N-113W, LOT 3 ORIGINAL WELLS NLB 46-33 PW 00466-50-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: NWNE 33-28N-113W ORIGINAL WELLS NLB 46-33 PW 00466-50-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 )TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: NWNE 33-28N-113W ORIGINAL WELLS NLB 48-04 PW 00466-60-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 4-27N-113W, NWSE ORIGINAL WELLS NLB 48-04 PW 00466-60-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 4-27N-113W, NWSE ORIGINAL WELLS NLB 49-09 PW 00466-70-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 9-27N-113W, NWNE ORIGINAL WELLS NLB 49-09 PW 00466-70-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 9-27N-113W, NWNE ORIGINAL WELLS NLB 51-16 PW 01980-80-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 16-27N-113W, NENE ORIGINAL WELLS NLB 51-16 PW 01980-80-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 16-27N-113W, NENE ORIGINAL WELLS NLB 52-16 PW 00154-10-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, NWSE ORIGINAL WELLS NLB 52-16 PW 00154-10-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 16-27N-113W, NWSE ORIGINAL WELLS NLB 53-21 PW 00154-20-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENW ORIGINAL WELLS NLB 53-21 PW 00154-20-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 21-27N-113W, NENW ORIGINAL WELLS NLB 54-20 PW 00154-30-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, SWNE ORIGINAL WELLS NLB 54-20 PW 00154-30-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 20-27N-113W, SWNE ORIGINAL WELLS NLB 55-17 PW 00466-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 17-27N-113W, SWSE ORIGINAL WELLS NLB 56-17 PW 00467-00-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 17-27N-113W, SENW ORIGINAL WELLS NLB 56-17 PW 00467-00-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 17-27N-113W, SENW ORIGINAL WELLS NLB 59-09 PW 00107-90-00-1 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWNW ORIGINAL WELLS NLB 59-09 PW 00107-90-00-2 WY SUBLETTE 1.0000000 .8510301 1.0000000 .8510301 (TGS) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SEC. 9-27N-113W, NWNW ORIGINAL WELLS NPC 1-30 LW*01092-10-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: NENW 30-31N-113W ORIGINAL WELLS NPC 2-19 LW*00101-70-00-2 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW SEC 19-31N-113W ORIGINAL WELLS NPC 2-19 LW*00101-70-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 660' FNL & 1100' FWL {NWNW} SEC. 19-31N-113W ORIGINAL WELLS PSU 12-30 PW*00490-80-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (NESW) ORIGINAL WELLS PSU 25-30 P&A*00491-50-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 WIW PW OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (SENW) ORIGINAL WELLS PSU 29-02 *00491-80-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 PW(TA) OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 2-28N-112W (LOT 5) NENE ORIGINAL WELLS PSU 3-31 PW*00491-90-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 31-29N-112W (NENW) ORIGINAL WELLS PSU 5-31 PW*00492-30-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 31-29N-112W (NENW) ORIGINAL WELLS PSU 6-30 PW*00492-40-00-1 WY SUBLETTE 1.0000000 .8475507 1.0000000 .8475507 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: SEC 30-29N-112W (SESW) ORIGINAL WELLS PSU 7-31 PW*00492-50-00-1 WY SUBLETTE 1.0000000 .8475506 1.0000000 .8475506 OPERATOR: EOG FORMATION: P SAND DESCRIPTION: 1979' FNL & 668' FWL, SEC 31-29N-112W (SENW) ORIGINAL WELLS RED HILL 1-18 CW 00894-60-00-1 WY SUBLETTE .9487350 .8115174 .9487350 .8115174 OPERATOR: EOG FORMATION: FRONTIER A-B DESCRIPTION: NWNE 18-27N-112W ORIGINAL WELLS RIPPES DRAW LW 00503-00-00-1 WY SUBLETTE 1.0000000 .8270000 1.0000000 .8270000 1-15 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 1341' FEL, 1734' FSL, 15-30N-113WNWSE ORIGINAL WELLS RUBEN ALMY 3&4*99999-99-99-O WY SUBLETTE .6195350 .5052063 .6195350 .5052063 STRAY OPERATOR: EOG FORMATION: ALMY STRAY 3 & 4 DESCRIPTION: ALMY STRAY 3 & 4 ORIGINAL WELLS S 11-28 LW&*00407-40-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 28-30N-113W ORIGINAL WELLS S 14-21 LW&*00407-70-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NESE 21-30N-113W ORIGINAL WELLS S 18-21 LW00407-80-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 21-30N-113W ORIGINAL WELLS S 19-28 LW&*00407-90-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1980' FNL & 1930' FWL28-30N-113W (SENW) ORIGINAL WELLS S 2-21 LW&*00408-00-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 21-30N-113W ORIGINAL WELLS S 21-28 00408-20-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSE 28-30N-113W ORIGINAL WELLS S 22-33 LW00408-30-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: 1048' FNL & 661' FEL 33-30N-113WNENE ORIGINAL WELLS S 24-28 LW00408-40-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESW 28-30N-113W ORIGINAL WELLS S 25-34 LW 00408-50-00-1 WY SUBLETTE 1.0000000 .8325100 1.0000000 .8325100 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1950' FSL & 750' FWL, SEC. 34-30N-113W, (NWSW) ORIGINAL WELLS S 26-33 LW00408-60-00-1 WY SUBLETTE 1.0000000 .8217500 1.0000000 .8217500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NENW 33-30N-113W ORIGINAL WELLS S 27-33 LW00408-70-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2997' FSL, & 1369' FEL33-30N-113W(SWNE) ORIGINAL WELLS S 28-28 LW*00408-80-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 2880' FSL & 1601' FEL28-30N-113WSWSW ORIGINAL WELLS S 31-28 LW00408-90-00-1 WY SUBLETTE 1.0000000 .8170000 1.0000000 .8170000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NENW 28-30N-113W ORIGINAL WELLS S 32-33 LW00409-00-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 33-30N-113W ORIGINAL WELLS S 33-28 LW00409-10-00-1 WY SUBLETTE .5000000 .4095000 .5000000 .4095000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: 1926' FSL & 1159' FWL, 28-30N-113W NWSW ORIGINAL WELLS S 34-34 LW00409-20-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-30N-113W ORIGINAL WELLS S 35-03 LW00149-70-00-1 WY SUBLETTE 1.0000000 .8317500 1.0000000 .8317500 OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: 1010' FWL & 645' FNL, SEC. 3-29N-113W, (LOT 4) ORIGINAL WELLS S 4-34 LW*00409-40-00-1 WY SUBLETTE 1.0000000 .8325000 1.0000000 .8325000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SESE 34-30N-113W ORIGINAL WELLS S 40-33 LW00409-50-00-1 WY SUBLETTE 1.0000000 .8392500 1.0000000 .8392500 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWNE 33-30N-113W ORIGINAL WELLS S 50-21 LW00101-60-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: NWSW 21-30N-113W ORIGINAL WELLS S 6-21 LW&*00409-60-00-1 WY SUBLETTE 1.0000000 .8320000 1.0000000 .8320000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 21-30N-113W ORIGINAL WELLS S 7-36 LW*00409-70-00-1 WY SUBLETTE 1.0000000 .8250000 1.0000000 .8250000 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 36-30N-113W ORIGINAL WELLS SADDLE RIDGE- *99999-99-99-A WY SUBLETTE 1.0000000 .7848011 1.0000000 .7848011 MESV OPERATOR: EOG FORMATION: MESAVERDE DESCRIPTION: MESAVERDE PA ORIGINAL WELLS SFE FED 4-24 CW&*00168-50-00-1 WY SUBLETTE 1.0000000 .8020060 1.0000000 .8020060 OPERATOR: EOG . FORMATION: TRANSITION DESCRIPTION: 1316' FWL & 1318' FNL, 24-28N-113W (NWNW) ORIGINAL WELLS SHB 1-08 (M) CW00519-20-00-1 WY SUBLETTE .9500000 .7748750 .9500000 .7748750 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 1308 FNL 1388 FEL NWNE-8-26N-113W (HOGBACK PROSPECT) ORIGINAL WELLS SLB 2-28 VPU00528-40-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2 DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 2-28 VPU00528-40-00-2 WY SUBLETTE 1.0000000 .7628571 1.0000000 .7628571 (BAXTER) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 2-28 VPU00528-40-00-3 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWNW ORIGINAL WELLS SLB 3-33 CW 00528-70-00-2 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 (BAX) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 542'FSL & 370'FWL33-27N-113WSWSW ORIGINAL WELLS SLB 3-33 CW 00528-70-00-3 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 (FRONT) OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: 542'FSL & 370' FWL33-27N-113W SWSW ORIGINAL WELLS SLB 3-33 CW 00528-70-00-1 WY SUBLETTE 1.0000000 .8543228 1.0000000 .8543228 (MUD) OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: 542'FSL & 370' FWL33-27N-113W SWSW ORIGINAL WELLS SLB 4-33 00528-80-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: MUDDY DESCRIPTION: SESE 33-27N-113W ORIGINAL WELLS SLB 5-33 LW 00154-50-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (BAXTER) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 2050' FNL & 2450' FEL 33-27N-113W SWNE ORIGINAL WELLS SLB 5-33 LW 00154-50-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (FR 1) OPERATOR: EOG FORMATION: FRONTIER 1 (TGS) DESCRIPTION: 2050' FNL & 2450' FEL, SEC. 33-27N-113W, (SWNE) ORIGINAL WELLS SLB 5-33 LW 00154-50-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (MUDDY) OPERATOR: EOG FORMATION: MUDDY/FRONTIER 2 DESCRIPTION: 2050' FNL & 2450' FEL, SEC. 33-27N-113W, (SWNE) ORIGINAL WELLS SLB 6-28 VPU00528-90-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2/MUDDY DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 6-28 VPU00528-90-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 6-28 VPU 00528-90-00-3 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWNE ORIGINAL WELLS SLB 7-28 AVPU00529-00-00-1 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: FRONTIER 2/MUDDY DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS SLB 7-28 AVPU00529-00-00-2 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS SLB 7-28A VPU 00529-00-00-3 WY SUBLETTE 1.0000000 .8328571 1.0000000 .8328571 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: SEC. 28-27N-113W, SWSW ORIGINAL WELLS SLB 8-33 LW 00154-60-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 AND MUDDY DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 8-33 LW 00154-60-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 8-33 LW 00154-60-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (TGS) OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 1850' FNL & 1150' FWL, SEC. 33-27N-113W, (SWNW) ORIGINAL WELLS SLB 9-33 LW 00154-90-00-1 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 2 AND MUDDY DESCRIPTION: 1053' FSL & 2417' FEL, SEC. 33-27N-113W, (SWSE) ORIGINAL WELLS SLB 9-33 LW 00154-90-00-2 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 (BAXTER) OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: 1053' FSL & 2417' FEL 33-27N-113W SWSE ORIGINAL WELLS SLB 9-33 TGS LW 00154-90-00-3 WY SUBLETTE 1.0000000 .8200000 1.0000000 .8200000 OPERATOR: EOG FORMATION: FRONTIER 1 DESCRIPTION: 1053' FSL & 2417' FEL, SEC. 33-27N-113W, (SWSE) ORIGINAL WELLS STAR CORRAL *99999-99-99-B WY SUBLETTE 1.0000000 .8289655 1.0000000 .8289655 UNIT OPERATOR: EOG FORMATION: ALMY DESCRIPTION: ALMY FORMATION PA "A" ORIGINAL WELLS SUPERIOR #1*00605-70-00-1 WY SUBLETTE 1.0000000 .8500000 1.0000000 .8500000 MARSHALL OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWSW 34-30N-113W ORIGINAL WELLS TAR ISL 1-33 LW&*00608-20-00-1 WY SUBLETTE 1.0000000 .8450000 1.0000000 .8450000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: NWSE 33-28N-112W ORIGINAL WELLS TAR ISL 2-33 &*00608-30-00-1 WY SUBLETTE 1.0000000 .8125000 .5000000 .4225000 LW(TA) OPERATOR: EOG FORMATION: ALMY DESCRIPTION: NWSE-33-28N-112W ORIGINAL WELLS TERM. DRAW CW 01974-60-00-1 WY SUBLETTE 1.0000000 .8325837 1.0000000 .8325837 3-15 OPERATOR: EOG FORMATION: BAXTER DESCRIPTION: SEC. 15-28N-113W, NWSW ORIGINAL WELLS THOMPSON 2-08 LW*00612-40-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: FRONTIER DESCRIPTION: SESE 8-29N-113W ORIGINAL WELLS THOMPSON 3-08 LW*00612-50-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 OPERATOR: EOG FORMATION: TRANSITION DESCRIPTION: SESE 8-29N-113W ORIGINAL WELLS TRESNER ST LW*00156-20-00-1 WY SUBLETTE 1.0000000 .8750000 1.0000000 .8750000 5-36 OPERATOR: EOG FORMATION: ALMY DESCRIPTION: SWNE 36-29N-113W ORIGINAL WELLS TRUE FED LW*01430-50-00-1 WY SUBLETTE .2653600 .2231580 .2653600 .2231580 10-22 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NW 22-27N-111W ORIGINAL WELLS FEDERAL 30-04 LW*00112-60-00-1 WY SWEETWATER .0686748 .0515061 .0343370 .0276416 OPERATOR: PRESIDIO OIL COMPANYFORMATION: FRONTIER AND OR BEAR RIVER DESCRIPTION: NESW 4-26N-111W ORIGINAL WELLS NORTH RUGER 02188-50-00-1 WY SWEETWATER .8750000 .6837500 .7000000 .5700000 34-29 OPERATOR: EOG FORMATION: ALMOND DESCRIPTION: 1120' FSL & 1920' FEL29-15N-94W SWSE ORIGINAL WELLS
EX-10.40 15 CREDIT AGREEMENT BETWEEN ENRON AND TRINIDAD LTD EXHIBIT 10.40 CREDIT AGREEMENT Between ENRON GAS & OIL TRINIDAD LIMITED, as Borrower and CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST, as Lender Dated as of March 8, 1994 TABLE OF CONTENTS Page ARTICLE 1 DEFINITIONS . . . . . . . . . . . . . . . . . . . 1 SECTION 1.1. Certain Defined Terms . . . . . . . . . . . . 1 SECTION 1.2. Computation of Time Periods . . . . . . . . . 9 ARTICLE 2 AMOUNTS AND TERMS OF THE ADVANCES . . . . . . . . 10 SECTION 2.1. The Advances . . . . . . . . . . . . . . . . . 10 SECTION 2.2. Making the Advances . . . . . . . . . . . . . 10 SECTION 2.3. Repayment of Principal . . . . . . . . . . . . 11 SECTION 2.4. Payment of Interest . . . . . . . . . . . . . 11 (a) Interest Rate . . . . . . . . . . . . . . . . . . . 11 (b) Interest Periods . . . . . . . . . . . . . . . . . 12 (c) Interest Payment Dates . . . . . . . . . . . . . . 12 SECTION 2.5. Mandatory Prepayment . . . . . . . . . . . . . 12 SECTION 2.6. Mandatory Interest Rate Conversion . . . . . . 13 SECTION 2.7. Illegality . . . . . . . . . . . . . . . . . . 14 SECTION 2.8. Payments and Computations . . . . . . . . . . 14 SECTION 2.9. Taxes . . . . . . . . . . . . . . . . . . . . 16 ARTICLE 3 CONDITIONS OF LENDING . . . . . . . . . . . . . . 17 SECTION 3.1. Condition Precedent to the Initial Advance . . . . . . . . . . . . . . . . . . 17 SECTION 3.2. Condition Precedent to All Advances . . . . . 19 SECTION 3.3. Additional Conditions Precedent to Fund or Maintain Advances with 936 Funds . . . . . . 21 ARTICLE 4 REPRESENTATIONS AND WARRANTIES . . . . . . . . . . 22 SECTION 4.1. Representations and Warranties of the Borrower . . . . . . . . . . . . . . . . . . 22 ARTICLE 5 COVENANTS OF THE BORROWER . . . . . . . . . . . . 26 SECTION 5.1. Affirmative Covenants . . . . . . . . . . . . 26 (a) Reporting Requirements . . . . . . . . . . . . . . 26 (b) Inspection Rights . . . . . . . . . . . . . . . . 27 (c) 936 Funds Advances . . . . . . . . . . . . . . . . 27 SECTION 5.2. Negative Covenants . . . . . . . . . . . . . . 29 ARTICLE 6 EVENTS OF DEFAULT . . . . . . . . . . . . . . . . 31 SECTION 6.1. Events of Default . . . . . . . . . . . . . . 31 -ii- ARTICLE 7 MISCELLANEOUS . . . . . . . . . . . . . . . . . . 33 SECTION 7.1. Amendments, Etc. . . . . . . . . . . . . . . . 33 SECTION 7.2. Notices . . . . . . . . . . . . . . . . . . . 33 SECTION 7.3. No Waiver; Remedies . . . . . . . . . . . . . 35 SECTION 7.4. Accounting Terms; Currency Equivalent . . . . 35 SECTION 7.5. Costs and Expenses; Indemnification. . . . . . 35 SECTION 7.6. Judgment . . . . . . . . . . . . . . . . . . . 38 SECTION 7.7. Consent to Jurisdiction; Waiver of Immunities . . . . . . . . . . . . . . . . . 38 SECTION 7.8. Binding Effect . . . . . . . . . . . . . . . . 40 SECTION 7.9. Governing Law . . . . . . . . . . . . . . . . 40 SECTION 7.10. Execution in Counterparts . . . . . . . . . . 40 SECTION 7.11. Limitation on Interest . . . . . . . . . . . . 41 SECTION 7.12. Sale of Note, Participations and Commitments . . . . . . . . . . . . . . . . . 41 SECTION 7.13. Severability of Provisions . . . . . . . . . . 41 Exhibit A - Form of Promissory Note Exhibit B - Items of Project Cost Eligible for 936 Funds Financing Exhibit C - Form of Opinion of Counsel for the Borrower Exhibit D - Form of Letter of the Process Agent Exhibit E - Form of Request for Advance Exhibit F - Form of Certification as to Qualified Recipient Status Required by Treas. Reg. Section 1.936-10(c)(11)(i) Exhibit G - Form of Borrower's Certificate Required under Section 6.4.3(a)(iii) of Regulation 3582 Exhibit H - Form of Certification Required by Treas. Reg. Section 1.936-10(c)12 and Section 5.1 of Regulation 3703 CREDIT AGREEMENT Dated as of March 8, 1994 ENRON GAS & OIL TRINIDAD LIMITED, a company organized and existing under the laws of Trinidad & Tobago and CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST ("CREDIT"), a trust organized and existing under the laws of the Commonwealth of Puerto Rico, agree as follows: ARTICLE 1 DEFINITIONS SECTION 1.1. CERTAIN DEFINED TERMS. As used in this Agreement, the following terms shall have the following meanings (such meanings to be equally applicable to both the singular and plural forms of the terms defined): "ADVANCE" means an advance by CREDIT to the Borrower pursuant to Article 2. "AGREEMENT" means this Credit Agreement with all its Exhibits. "APPLICABLE LIBID RATE" means, with respect to a particular Advance and a particular Interest Period, the rate obtained by multiplying the LIBID Rate, as determined by the Indexing Agent to be in effect on the applicable Interest Rate Determination Date for such Advance and such Interest Period, by the fixed percentage applicable to such Advance determined as provided in Section 2.4. "BASE RATE" means, for any Interest Period, a fluctuating annual rate of interest which shall at all times be equal to the 2 rate of interest announced publicly by Citibank, N.A. in New York, New York, from time to time, as its base rate. "BORROWER" means Enron Gas & Oil Trinidad Limited, a company organized and existing under the laws of Trinidad & Tobago. "BUSINESS DAY" means a day of the year in which commercial banks are not required or authorized to close and are not otherwise closed to the public in Port of Spain, Trinidad, San Juan, Puerto Rico, or New York, New York. "CHANGE IN TAX LAW" has the meaning specified in Section 2.6. "CODE" means the United States Internal Revenue Code of 1986, as amended, and the regulations promulgated thereunder. "COMMITMENT" has the meaning specified in Section 2.1. "COMMISSIONER" means the Commissioner of Financial Institutions of the Commonwealth. "COMMONWEALTH" means the Commonwealth of Puerto Rico. "CREDIT" means Caribbean Regional Development Investment Trust. "CREDIT NOTES" means promissory notes issued by CREDIT the proceeds of which are used to fund the Advances made hereunder. "DOLLARS" and the sign "$" each means lawful money of the United States. "ELIGIBLE ACTIVITY" has the meaning given such term in Regulation 3582. 3 "ELIGIBLE FUNDS" has the meaning given such term in Regulation 3582. "ELIGIBLE INSTITUTION" has the meaning given such term in Regulation 3582. "EVENT OF DEFAULT" has the meaning specified in Section 6.1. "EVENT OF TAXABILITY" has the meaning specified in Section 2.5. "FEDERAL CBI REGULATIONS" means the regulations issued by the United States Internal Revenue Service on May 13, 1991 under Section 936(d)(4) of the Code (26 C.F.R. Sec. 1.936-10 (1991)), as such regulations may be amended from time to time, or any successor regulation. "GOVERNMENT APPROVALS" means any applicable consent, permit, license or other approval issued by any agency, department, bureau, division or other instrumentality of any Governmental Authority. "GOVERNMENTAL AUTHORITY" means any municipal, county, Commonwealth, state or federal governmental authority or other governmental authority (domestic or foreign) having or claiming jurisdiction over the Project, the Borrower, CREDIT or the transactions contemplated in this Agreement. "INDEMNIFIED PARTY" has the meaning specified in Section 7.5(b) hereof. "INDEBTEDNESS" means (i) indebtedness for borrowed money, (ii) obligations evidenced by bonds, debentures, notes or other similar instruments, (iii) obligations to pay the deferred purchase 4 price of property or services (including, but not limited to, trade debt), and (iv) obligations under direct or indirect guaranties in respect of, and obligations (contingent or otherwise) to purchase or otherwise acquire, or otherwise to assure a creditor against loss in respect of, indebtedness or obligations of others of the kinds referred to in (i) through (iii) above. "INDEXING AGENT" means Citibank, N.A. and any other person that, with the consent of the Trustee and the Borrower, assumes the obligation to act as Indexing Agent hereunder. "INTEREST PAYMENT DATE" has the meaning specified in Section 2.4(c) hereof. "INTEREST PERIOD" has the meaning specified in Section 2.4(b) hereof. "INTEREST RATE DETERMINATION DATE" means with respect to each Interest Period, the Mutual Business Day immediately preceding the first day of such Interest Period. "INVESTMENT IN ACTIVE BUSINESS ASSETS" has the meaning given such term in the Federal CBI Regulations. "LENDING OFFICE" means the office of the Trustee located at 221 Ponce de Leon Avenue, Hato Rey, San Juan, Puerto Rico or any other office of the Trustee from which Advances are made or maintained and for the account of which all payments of principal of, and interest on, such Advances are made, as hereafter notified to the Borrower from time to time by the Trustee. "LETTER OF CREDIT" means the irrevocable, transferable, direct-pay letter of credit, substantially in the form of Exhibit A to the Reimbursement Agreement, issued by the Letter of Credit 5 Bank in the principal amount of $31,000,000 plus 100 days' interest thereon at the rate of 10% per annum. "LETTER OF CREDIT BANK" means Credit Suisse, New York Branch, a banking institution organized and existing under the laws of Switzerland and licensed by the New York State Banking Department. "LIBID RATE" means, as of any particular Interest Rate Determination Date, the offered quotation for the rate of interest (expressed out to the sixth decimal place and truncated thereafter) on three-month deposits of Dollars in the London interbank market, as published by Telerate Systems, Inc. (currently on page 3750 of the financial information reporting services furnished electronically by Telerate Systems, Inc.) at approximately 11:00 a.m. (London time) on such date, less 1/8 of 1%. If, as of any Interest Rate Determination Date, the LIBID Rate cannot be ascertained on the foregoing basis, such rate shall be Citibank, N.A's offered quotation to leading banks in the London interbank market for three-month deposits of Dollars at 11:00 a.m. (London time) on the date in question, less 1/8 of 1%. If as of any particular Interest Rate Determination Date the LIBID Rate cannot be determined on the basis of any of the foregoing methods, the LIBID Rate in effect for the Interest Period about to end shall continue in effect for the succeeding Interest Period. "LOAN DOCUMENTS" means this Agreement with its Exhibits, the Notes and any other documents executed pursuant to or in connection with this Agreement. "LOAN PARTY(IES)" means each Person who is a party to the Loan Documents. "MATURITY DATE" means, with respect to each Advance, such date as shall be agreed to by CREDIT and the Borrower on or prior 6 to the date such Advance is made as the date when the principal amount of such Advance must be paid in full, such date never exceeding four years and three months from the date such Advance is made. "MUTUAL BUSINESS DAY" means any day that is not a Saturday, Sunday or other day on which banking institutions in either Port of Spain, Trinidad, New York, New York, San Juan, Puerto Rico, or London, England are authorized or obligated by law or executive order to be closed or are otherwise closed to the public. "936 COVENANTS" means the covenants set forth in Section 5.1(c) hereof. "936 ELIGIBLE COSTS" means those costs of the type described in Exhibit B that are or were incurred by the Borrower after March 25, 1993 in connection with the Project. "936 FUNDS" means Eligible Funds received by CREDIT from the sale of the CREDIT Notes. "936 INDEMNITY LOSSES" has the meaning specified in Section 7.5(c) hereof. "NOTE" means a promissory note of the Borrower, which shall be expressly subject to the laws of the Commonwealth, payable to the order of CREDIT, in substantially the form of Exhibit A hereto, evidencing the indebtedness of the Borrower resulting from each Advance made by CREDIT. "OTHER TAXES" has the meaning specified in Section 2.9(b). 7 "PERSON" means an individual, partnership, corporation (including a business trust), joint stock company, trust, unincorporated organization, joint venture or other entity, or a government or any subdivision or agency thereof. "PRINCIPAL PAYMENT DATE" means the Maturity Date of each Advance, or, if earlier, the day on which the Borrower is required to pay in full the outstanding principal amount of any or all Advances pursuant to Sections 2.5, 2.7 and 6.1. "PROCESS AGENT" has the meaning specified in Section 7.7(a). "PROJECT" means the development of gas and oil fields off the coast of Trinidad & Tobago, including the construction of off-shore platforms, laying of pipelines and drilling of production wells. "PUERTO RICO REGULATIONS" means Regulation 3582 and Regulation 5002, collectively. "QUALIFIED CARIBBEAN BASIN COUNTRY" has the meaning provided in Section 936(d)(4)(B) of the Code and the Federal CBI Regulations. "QUALIFIED CBI INVESTMENT" means an investment that meets the requirements provided in Section 936(d)(4) of the Code and the Federal CBI Regulations. "QUALIFIED RECIPIENT" has the meaning given such term in the Federal CBI Regulations. "REGULATION 3582" means Regulation Number 3582 issued by the Commissioner on January 29, 1988, as such regulation may be 8 amended from time to time, or any successor regulation issued by said official or by any successor governmental agency. "REGULATION 5002" means Regulation Number 5002 approved on November 17, 1993, effective on January 6, 1994, as such regulation may be amended from time to time, or any successor regulation issued by said official or by any successor governmental agency. "REIMBURSEMENT AGREEMENT" means the Reimbursement Agreement, dated as of March 8, 1994 between the Borrower and the Letter of Credit Bank, providing for, among other things, the issuance of the Letter of Credit, together with all agreements supplemental thereto or amendatory thereof. "REQUEST FOR ADVANCE" has the meaning specified in Section 3.2(a)(i) hereof. "SUBSIDIARY" means any corporation of which more than 50% of the outstanding capital stock having ordinary voting power to elect a majority of the Board of Directors of such corporation (irrespective of whether or not at the time capital stock of any other class or classes of such corporation shall or might have voting power upon the occurrence of any contingency) is at the time directly or indirectly owned by the Borrower, by the Borrower and one or more other Subsidiaries, or by one or more other Subsidiaries. "TAXABLE RATE" means, in the case of an Advance that bears interest at a fixed rate, the rate that shall have been agreed to in writing by the Borrower and CREDIT, on or prior to the time such Advance is made, as the rate that shall apply to such Advance upon the occurrence of a Change in Tax Law, and in the case of an Advance that bears interest at a floating rate, a rate equal 9 to twelve and one-half (12.5) basis points over and above the LIBID Rate. "TAXES" has the meaning specified in Section 2.9 hereof. "TERMINATION DATE" means the day numerically corresponding to the date of this Agreement in the twelfth month following the date of this Agreement. "TRUSTEE" means Banco Central Hispano-Puerto Rico (formerly Banco Central Corp.), the Trustee under that certain Deed of Constitution of Trust dated August 4, 1992, establishing CREDIT. "UNAVOIDABLE DELAYS" means delays due to strikes, lockouts, acts of God, governmental restrictions, failure or inability to secure materials or labor by reason of priority or similar regulation or order of any governmental or regulatory body, enemy action, civil disturbance, fire, unavoidable hindrance or any other act beyond the reasonable control of Borrower, excluding, however the inability or failure of Borrower to obtain any financing which may be necessary to carry out its obligations under this Agreement; PROVIDED, HOWEVER, that, within ten days after the termination of the occurrence which caused any such delay, Borrower shall have given written notice to the Bank of the cause of delay and the period of time during which it existed, and the period of the Unavoidable Delay shall be such period of time during which the particular delay existed. "UNITED STATES" and "U.S." each means United States of America. SECTION 1.2. COMPUTATION OF TIME PERIODS. In this Agreement, in the computation of periods of time from a specified date to a later specified date, the word "from" means "from and including" and the words "to" and "until" each means "to but excluding". 10 ARTICLE 2 AMOUNTS AND TERMS OF THE ADVANCES SECTION 2.1. THE ADVANCES. CREDIT agrees, on the terms and conditions hereinafter set forth, to make Advances to the Borrower from time to time on any Business Day during the period from the date hereof until the Termination Date or the date of termination in whole of CREDIT's obligation to make or maintain Advances pursuant to Section 2.5, 2.7, or Section 6.1 in an aggregate amount not to exceed at any time outstanding U.S.$75,000,000 (the "Commitment"). Each Advance shall reduce the amount of the Commitment by the principal amount of such Advance. Each Advance shall be in an aggregate amount of not less than $5,000,000 or an integral multiple of $1,000,000 in excess thereof (except that the last Advance may be in an amount equal to the then unused portion of the Commitment) and shall not be made within ten (10) calendar days of the date of any other Advance. SECTION 2.2. MAKING THE ADVANCES. (a) Each Advance shall be made after receipt by CREDIT of notice from the Borrower, given not later than 11:00 a.m. (San Juan, Puerto Rico time) on the fifth (5th) Business Day (one (1) Business Day in the case of the initial Advance) prior to the date of the proposed Advance. Such notice shall specify the requested date and amount of the proposed Advance. A Request for Advance shall be delivered only after the condition set forth in Section 3.2(c) shall have been satisfied with respect to such Advance. Not later than 11:00 a.m. (San Juan, Puerto Rico time) on the date of such Advance and upon fulfillment of the applicable conditions set forth in Article 3, CREDIT will make such Advance available to the Borrower in same day funds at its Lending Office. (b) In the event that the Borrower revokes any notice to CREDIT requesting an Advance or if the Borrower fails to fulfill on or before the date specified in such notice for such Advance the 11 applicable conditions set forth in Article 3, the Borrower shall indemnify CREDIT against any loss, cost or expense incurred by CREDIT as a result thereof, including, without limitation, any loss (excluding loss of anticipated profits), cost or expense incurred by reason of the liquidation or reemployment of funds acquired by CREDIT to fund such Advance when such Advance, as a result of such failure, is not made on such date. SECTION 2.3. REPAYMENT OF PRINCIPAL. The Borrower shall repay the aggregate principal amount of each Advance on its Maturity Date. Except as otherwise provided hereunder, the Borrower may not prepay any of the principal amount of the Advances made hereunder. SECTION 2.4. PAYMENT OF INTEREST. (a) INTEREST RATE. (i) The Borrower shall pay interest on the unpaid principal amount of each Advance from the date of such Advance until the date such Advance is paid in full at an interest rate per annum which shall be either (A) such fixed rate per annum as shall have been agreed to by the Borrower and CREDIT prior to the date such Advance is made or (B) a floating rate which at all times during each Interest Period shall be equal to the Applicable LIBID Rate as determined by the Indexing Agent on each applicable Interest Rate Determination Date. (ii) Notwithstanding anything else contained herein, the rate applicable to any Advance outstanding after the Maturity Date or after such Advance is declared due and payable pursuant to Section 6.1 hereof shall be the Base Rate plus 5/8 of 1%. (iii) The fixed percentage of the LIBID Rate used to determine the Applicable LIBID Rate for each Advance shall be the percentage agreed to in writing by the Borrower and CREDIT prior to the date such Advance is made. 12 (b) INTEREST PERIODS. The period between the date of each Advance and the Maturity Date shall be divided into successive periods, each such period being an "Interest Period" for such Advance. The Interest Period for each Advance shall be the three calendar month period beginning on January 1, April 1, July 1 and October 1, except that: (i) the initial Interest Period for each Advance shall begin on the day such Advance is made and shall end on the day preceding the immediately succeeding Interest Payment Date; and (ii) the last Interest Period for each Advance shall end on its Principal Payment Date. (c) INTEREST PAYMENT DATES. Interest due on each Advance shall be payable (i) quarterly in arrears on the first day of each of the months of January, April, July and October (each an "Interest Payment Date"), commencing on the first of such dates to occur after the date on which the Advance is made, and (ii) on the date on which the Advance is paid in full, each payment being made for the actual number of days elapsed since the last Interest Payment Date for which interest was paid or, in the case of the first Interest Payment Date, since the date the Advance was made. SECTION 2.5. MANDATORY PREPAYMENT. The Borrower shall be obligated and agrees to prepay any Advance immediately upon the occurrence of an Event of Taxability. An "Event of Taxability" shall be deemed to have occurred (i) on the date an official announcement of a Governmental Authority is made that Trinidad & Tobago has ceased to be a Qualified Caribbean Basin Country or on the date that CREDIT has ceased to be a Qualified Financial Institution, or (ii) 60 days after (1) the Trustee in its sole discretion, or any Governmental Authority, determines that such Advance does not constitute an Eligible Activity or a Qualified CBI Investment for any reason other than those provided in clause (i) (including, without limitation, as a result of any change in 13 any applicable law or regulation, or in the interpretation thereof), (2) the Borrower does not permit the Trustee to discharge or fulfill its duties and obligations under the Puerto Rico Regulations or the Federal CBI Regulations or the Borrower fails to comply with the 936 Covenants, (3) it has come to the attention of the Trustee that any of the representations, covenants or conditions set forth in Sections 4.1(j), (n), (o) and (p) and 5.1(c) of this Agreement have been breached or cannot be complied with; or (4) the Trustee has received the opinion of the independent public accountants of the Borrower provided in Section 5.1(c)(v) hereof, stating that during the preceding taxable year the Borrower has failed to comply with the representation provided in Section 4.1(p) or that they have reasons to doubt that the loan proceeds have been properly used to pay Eligible Projects Costs; PROVIDED, HOWEVER, that notwithstanding the occurrence of any event described in clauses (ii) (1), (2), (3) or (4), an Event of Taxability shall not be deemed to have occurred if within the sixty (60) day period therein provided, the Borrower submits to the Trustee, an opinion of counsel reasonably acceptable to the Trustee to the effect that notwithstanding the occurrence of any such event the interest payable by CREDIT on the Credit Notes nevertheless (i) continues to constitute qualified possession source investment income under Section 936 of the Code, or (ii) is otherwise (x) excludable from gross income for federal income tax purposes by any corporation that qualifies for and has in effect an election under Section 936 of the Code, or (y) eligible for the credit against federal income taxes provided by Section 936 of the Code, or an equivalent credit. SECTION 2.6. MANDATORY INTEREST RATE CONVERSION. Upon the occurrence of a "Change in Tax Law," the interest rate on each Advance hereunder will be automatically adjusted to the Taxable Rate, such adjustment being effective on the earliest day when the Change in Tax Law may become effective. A "Change in Tax Law" shall mean, and shall be deemed to have occurred upon, the enactment of an amendment to the Code that, in the opinion of 14 recognized tax counsel knowledgeable in federal tax matters selected by the Trustee and reasonably acceptable to the Borrower, (i) either (A) repeals Section 936 of the Code ("Section 936"), (B) has the effect of making the interest on the related CREDIT Notes received by a corporation that qualifies for and has in effect an election under Section 936 (a "936 Corporation") fully or partially subject to federal income tax, or (C) has the effect directly or indirectly of limiting the amount of investment income actually derived by a 936 Corporation that can be covered by the credit provided under Section 936 as in effect on the date the related CREDIT Notes are delivered (the "936 Credit") through the imposition of a limitation (including, without limitation, a wage based credit) on the total credit that can be claimed under Section 936 or some other limitation; and (ii) does not provide to 936 Corporations an alternative credit, exemption or deduction that is (A) fully equivalent from the standpoint of federal income tax benefits to the 936 Credit, and (B) available to all 936 Corporations without having to qualify for or make a special election. SECTION 2.7. ILLEGALITY. Notwithstanding any other provision of this Agreement, if there shall be an introduction of or any change in or in the interpretation of any law or regulation that makes it unlawful, or if any central bank or other Governmental Authority asserts that it is unlawful, for the Trustee to perform its obligations hereunder to make, fund or maintain Advances or, if the rate applicable to any Advance hereunder shall at any time exceed the maximum rate permitted by applicable law, then, upon notification thereof to the Borrower specifying the reasons therefor the Borrower shall forthwith prepay in full all Advances then outstanding together with interest accrued thereon. SECTION 2.8. PAYMENTS AND COMPUTATIONS. (a) On or no more than one Business Day prior to each Interest Payment Date and Principal Payment Date, the Trustee shall make a drawing under the Letter of Credit in an amount equal to the principal and/or 15 interest due on such date so that by 11:00 a.m. (San Juan, Puerto Rico time) the Trustee shall have sufficient immediately available funds with which to pay the interest on and principal of the CREDIT Notes due on such day. Should the Letter of Credit Bank fail to make the required payment, the Borrower shall be required to make such payment not later than 11:00 a.m. (San Juan, Puerto Rico time) on the following Business Day in Dollars. Such payment shall be made to the Trustee at its address referred to in Section 7.2 in same day funds. (b) All computations of interest shall be made by the Trustee on the basis of a year of 360 days for the actual number of days (including the first day but excluding the last day) occurring in the period for which such interest is payable (except that whenever interest shall be determined on the basis of the Base Rate such interest shall be computed on the basis of a 365/366 day year). Each determination by the Trustee of an interest rate hereunder shall be conclusive and binding for all purposes, absent manifest error. (c) Whenever any payment hereunder or under the Note shall be stated to be due on a day other than a Business Day, such payment shall be made on the next succeeding Business Day, and such extension of time shall in such case be excluded in the computation of payment of interest. (d) To the fullest extent permitted by law, the Borrower shall make all outstanding payments due hereunder and under each Note regardless of any defense or counterclaim, including, without limitation, any defense or counterclaim based on any law, rule or policy which is now or hereafter promulgated by any Governmental Authority or regulatory body and which may adversely affect the Borrower's obligation to make, or the right of CREDIT to receive, such payments. This provision and any payment made while such defense or counterclaim exists shall not be interpreted as a waiver 16 or a release by the Borrower of any counterclaim which it may assert against CREDIT. SECTION 2.9. TAXES. (a) Any and all payments by the Borrower hereunder and under each Note shall be made, in accordance with Section 2.8, free and clear of and without deduction for any and all present or future taxes, levies, imposts, deductions, charges or withholdings imposed by a Governmental Authority of Trinidad & Tobago, and all liabilities with respect thereto (all such taxes, levies, imposts, deductions, charges, withholdings and liabilities being hereinafter referred to as "Taxes"). If the Borrower shall be required by law to deduct any Taxes from or in respect of any sum payable hereunder or under any Note, (i) the sum payable shall be increased as may be necessary so that after making all required deductions (including deductions applicable to additional sums payable under this Section 2.9) CREDIT receives an amount equal to the sum it would have received had no such deductions been made, (ii) the Borrower shall make such deductions and (iii) the Borrower shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law. In the event that CREDIT receives any credit or refund of any Taxes included in any payment made by the Borrower pursuant to the immediately preceding sentence, CREDIT shall thereupon reimburse the Borrower for the amount of such credit or refund actually received. (b) In addition, the Borrower agrees to pay any present or future stamp or documentary taxes or any other excise or property taxes, registry fees, charges or similar levies imposed by a Governmental Authority of Trinidad & Tobago which arise at any time from any payment made hereunder or under any Note or any other Loan Document or from the execution, delivery or registration of, or otherwise with respect to, this Agreement, a Note or any other Loan Document (hereinafter referred to as "Other Taxes"). 17 (c) The Borrower, to the fullest extent permitted by law, will indemnify CREDIT for the full amount of Taxes or Other Taxes (including, without limitation, any Taxes or Other Taxes imposed on amounts payable under this Section 2.9) paid by CREDIT or any liability (including penalties, interest and expenses) arising therefrom or with respect thereto, whether or not such Taxes or Other Taxes were correctly or legally asserted. This indemnification shall be made within thirty (30) days from the date CREDIT makes written demand therefor. (d) Within thirty (30) days after the date of any payment of Taxes, the Borrower will furnish to CREDIT at its address referred to in Section 7.2, the original or a certified copy of a receipt evidencing payment thereof. (e) Without prejudice to the survival of any other agreement of the Borrower hereunder, the agreements and obligations of the Borrower contained in this Section 2.9 shall survive the payment in full of principal and interest hereunder and under any Note for a period of five years thereafter. ARTICLE 3 CONDITIONS OF LENDING SECTION 3.1. CONDITION PRECEDENT TO THE INITIAL ADVANCE. The obligation of CREDIT to make the initial Advance is subject to the condition precedent that CREDIT shall have received, on or before the date of the initial Advance, the following, each dated such day, and each in form and substance satisfactory to CREDIT: (i) the Note; (ii) the Letter of Credit; 18 (iii) certified copies of the resolutions of the board of directors and, if required, the consents of the stockholders, of the Borrower approving each Loan Document to which it is a party, and of all documents evidencing other necessary corporate action and Governmental Approvals, if any, with respect to each such Loan Document; (iv) a certificate of the Secretary or an Assistant Secretary of the Borrower certifying the names and true signatures of the officers of the Borrower authorized to sign each Loan Document to which it is a party; (v) a copy of the Memorandum and Articles of Association of the Borrower, certified as being true and complete by the Secretary or an Assistant Secretary of the Borrower; (vi) the final budget of 936 Eligible Costs, a copy of which is attached hereto as Exhibit B, as approved by CREDIT; (vii) evidence satisfactory to CREDIT that the Governmental Authorities of Trinidad & Tobago have agreed to give satisfactory tax treatment to the Project and the financing thereof; (viii) evidence satisfactory to CREDIT that payment of all applicable taxes, impositions, assessments and other charges affecting the Project has been made; (ix) true copies of all necessary Governmental Approvals and other approvals (including exchange control approvals, if any) required with respect to the Project, the operations of the Borrower in Trinidad & Tobago and the transactions contemplated in this Agreement; 19 (x) a favorable opinion of Pietrantoni Mendez & Alvarez, counsel for CREDIT, as to such matters as CREDIT may reasonably request; (xi) a favorable opinion of M. Hamel Smith & Co., counsel for the Borrower, substantially in the form of Exhibit C hereto and as to such other matters as CREDIT may reasonably request; and (xii) a letter from the Process Agent, substantially in the form of Exhibit D hereto, agreeing to act as Process Agent and to forward forthwith all process received by it to the Borrower. SECTION 3.2. CONDITION PRECEDENT TO ALL ADVANCES. The obligation of CREDIT to make each Advance (including the initial Advance) shall be subject to the further conditions precedent that: (a) At least five (5) Business Days (one (1) Business Day in the case of the initial Advance) prior to the date of each Advance CREDIT shall have received: (i) a request for Advance executed by the Borrower substantially in the form of Exhibit E hereto (the "Request for Advance"), setting forth the nature of all 936 Eligible Costs for which such Advance is requested and the names of the obligees in respect of such 936 Eligible Costs and the respective amounts paid or owing and to be paid to each; and such further evidence (including receipted invoices and affidavits) as CREDIT may reasonably request showing that such 936 Eligible Costs have been or will be incurred and, in either case, will be paid within sixty (60) days (30 days in the case of funds that will be used to repay an interim borrowing) after the date of the Advance; and 20 (ii) a Note in the principal amount of the Advance requested together with such other instruments, documents and certificates as CREDIT may reasonably request; (b) On or before the date of the Advance (other than an Advance made on the date of executing this Agreement) (but not earlier than five (5) calendar days prior to the date of each Advance) a certificate signed by a duly authorized officer of the Borrower, dated the date of such Advance, stating that: (i) the representations and warranties contained in Section 4.1 of this Agreement and in the other Loan Documents to which it is a party, are correct on and as of the date of such Advance, before and after giving effect to such Advance and to the application of the proceeds therefrom, as though made on and as of such date; (ii) no event has occurred and is continuing, or would result from such Advance or from the application of the proceeds therefrom, which constitutes an Event of Default or would constitute an Event of Default but for the requirement that notice be given or time elapse or both; and (iii) no material adverse change has occurred concerning the Borrower or the Project or affecting the validity and enforceability of any Loan Document; and, (c) CREDIT Notes in an aggregate principal amount equal to the principal amount of such Advance shall have been sold by Citicorp Financial Services Corporation and the Borrower and CREDIT shall have agreed as to the fixed interest rate applicable to such Advance or, in the case of a floating rate, the fixed percentage used to determine the Applicable LIBID Rate for such Advance. 21 SECTION 3.3. ADDITIONAL CONDITIONS PRECEDENT TO FUND OR MAINTAIN ADVANCES WITH 936 FUNDS. The obligation of CREDIT to fund or maintain any Advance with 936 Funds shall be subject to the further conditions precedent that: (a) CREDIT shall have received a favorable opinion of Pietrantoni Mendez & Alvarez, Puerto Rico counsel for CREDIT, to the effect that the Advances to be made hereunder with 936 Funds in order to finance the 936 Eligible Costs would qualify as an Eligible Activity and Qualified CBI Investment, which opinion continues to be in full force and effect; (b) CREDIT shall have received the final approval from the Commissioner for the making of Advances to the Borrower and the funding of said Advances with 936 Funds, which approval remains in full force and effect; (c) Trinidad & Tobago remains a Qualified Caribbean Basin Country; (d) CREDIT remains an Eligible Institution; (e) the Borrower is engaged in the development of the Project and continues to be a Qualified Recipient; (f) the Advance qualifies as an Investment in Active Business Assets; (g) the Borrower has not violated any of the 936 Covenants; (h) the Borrower shall have submitted to CREDIT such information or documentation as CREDIT may reasonably require to satisfy its obligations under the Puerto Rico Regulations and the Federal CBI Regulations; 22 (i) there has not occurred, or in the reasonable opinion of CREDIT there is not likely to occur, any event or circumstance (including a change of law, regulation or in the interpretation thereof) as a result of which an Advance would not constitute an Eligible Activity or a Qualified CBI Investment, or that would give rise to an obligation by the Borrower to indemnify CREDIT under Section 7.5; (j) the Advance requested by the Borrower (as evidenced by the Request for Advance submitted by the Borrower pursuant to Section 3.2(a)(i)) relates exclusively to 936 Eligible Costs; and (k) CREDIT shall have received representation letters and certificates with respect to the use of Advances funded with 936 Funds, substantially in the form of Exhibits F, G and H hereto. ARTICLE 4 REPRESENTATIONS AND WARRANTIES SECTION 4.1. REPRESENTATIONS AND WARRANTIES OF THE BORROWER. The Borrower represents and warrants as follows: (a) The Borrower is a limited liability company duly organized, validly existing and in good standing under the laws of Trinidad & Tobago and is, or will be, actively engaged in the development of the Project. (b) The execution, delivery and performance by the Borrower of this Agreement, each Note and the other Loan Documents to which it is or will be a party are within the Borrower's powers, have been duly authorized by all necessary corporate action, and do not contravene (i) the Borrower's Memorandum and Articles of Association or (ii) any treaty, law, rule, regulation, order, decree, writ, judgment, award, injunction or similar legal restriction applicable to the Borrower and its properties or 23 (iii) any contractual restriction contained in any indenture, loan or credit agreement, guaranty, debenture, mortgage, deed of trust, bond, note, or other agreement or instrument which binds or affects or purports to bind or affect the Borrower and its properties. (c) No authorization or approval (including exchange control approval) or other action by, and no notice to or filing with, any Governmental Authority or regulatory body or any other Person is required for the due execution, delivery and performance by the Borrower of this Agreement, each Note or any other Loan Document to which it is or will be a party. (d) This Agreement is, and each Note and the other Loan Documents to which the Borrower is a party are, the legal, valid and binding obligations of the Borrower enforceable against the Borrower in accordance with their respective terms, except as the enforceability thereof may be limited by the effect of any applicable bankruptcy, insolvency, reorganization, moratorium, or similar laws affecting creditors' rights generally. (e) The obligations of the Borrower under this Agreement and each Note rank and will rank at least PARI PASSU in priority of payment and in all other respects with all other Indebtedness of the Borrower. (f) There is no pending or threatened action or proceeding involving the Borrower before any court, Governmental Authority or arbitrator that may materially adversely affect the Project or the financial condition or operations of the Borrower or that purports to affect the legality, validity or enforceability of this Agreement, each Note or any other Loan Document. (g) The Borrower is subject to civil and commercial law with respect to its obligations under this Agreement, each Note and the other Loan Documents to which it is or will be a party, and the 24 execution, delivery and performance by the Borrower of this Agreement, each Note and the other Loan Documents to which it is or will be a party constitute private and commercial acts rather than public or governmental acts. Neither the Borrower nor any of its property has any immunity from jurisdiction of any court or from set-off or any legal process (whether through service or notice, attachment prior to judgment, attachment in aid of execution, execution or otherwise) under the laws of Trinidad & Tobago. (h) Except for the withholding tax of .001% on interest payments, there is no tax, stamp duty, levy, impost, deduction, charge or withholding tax imposed by Trinidad & Tobago or any political subdivision, taxing authority, or Governmental Authority thereof on or by virtue of the execution or delivery or performance of or payment of any amount under (i) this Agreement or any Note, or (ii) any other document to be furnished hereunder. (i) This Agreement is in proper legal form under the laws of Trinidad & Tobago for the enforcement thereof against the Borrower under the laws of Trinidad & Tobago; and to ensure the legality, validity, enforceability or admissibility in evidence of this Agreement, each Note or any other Loan Document in Trinidad & Tobago, it is not necessary that this Agreement, each Note, any other Loan Document, or any other document be filed or recorded with any court or other authority in Trinidad & Tobago or that any stamp or similar tax be paid on or in respect of this Agreement, each Note or any other Loan Document. (j) The proceeds of each Advance shall be used by the Borrower solely for the purpose of paying 936 Eligible Costs. (k) All material consents, approvals and permits of all Governmental Authorities having jurisdiction, or of any other Person, that are required for the design, development, construction 25 and operation of the Project, have been obtained and are in full force and effect. (l) The interest required to be paid under each Note, and the fees and the costs and expenses required to be paid hereunder are not usurious or otherwise illegal under the laws of Trinidad & Tobago. (m) No information, exhibit, schedule or report furnished by the Borrower to CREDIT in connection with the negotiation of this Agreement or pursuant to the terms of this Agreement contains any material misstatement of fact or omits to state a material fact or any fact necessary to make the statements contained therein not misleading. (n) The equipment included in the list of 936 Eligible Costs is new equipment or used equipment that has not been used in Trinidad & Tobago during the past 3 years. (o) All items included in Eligible Projects Costs (i) qualify as capital expenditures for purposes of paragraph (c)(8) of the Federal CBI Regulations, as now in effect, (ii) constitute an Investment in Active Business Assets and (iii) represent assets that are now owned or, at the time such costs are incurred, will be owned by the Borrower for Federal income tax purposes. (p) All of the interest that Borrower will pay under this Agreement will be considered foreign source interest income under the general sourcing rules of the Code. 26 ARTICLE 5 COVENANTS OF THE BORROWER SECTION 5.1. AFFIRMATIVE COVENANTS. So long as any Advance shall remain unpaid or CREDIT shall have any Commitment, the Borrower will, unless CREDIT shall otherwise consent in writing: (a) REPORTING REQUIREMENTS. Furnish to the Trustee: (i) as soon as available and in any event within ninety (90) days after the end of each fiscal year of the Borrower a copy of the audited financial statements for such year for the Borrower, including therein a balance sheet of the Borrower as of the end of such fiscal year, together with a certificate of a director of the Borrower knowledgeable about the Borrower's financial affairs stating that no Event of Default or event which, with notice or lapse of time or both, would constitute an Event of Default, has occurred and is continuing, or if, in the opinion of such director an Event of Default or such an event has occurred and is continuing, a statement as to the nature thereof; (ii) promptly after the commencement thereof, notice of all actions, suits and proceedings before any court or governmental department, commission, board, bureau, agency or instrumentality, domestic or foreign, that may have a material adverse effect on the Borrower or the Project; (iii) as soon as possible and in any event within ten (10) days after the occurrence of each Event of Default and each event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default, continuing on the date of such statement, a statement of a director of the Borrower setting forth details of such Event of Default or event and the action which the Borrower has taken and proposes to take with respect thereto; and 27 (iv) such other information respecting the business, properties, operations or condition, financial or otherwise, of the Borrower and the Project as CREDIT may from time to time reasonably request. (b) INSPECTION RIGHTS. At any reasonable time and from time to time, permit the Trustee or any agents or representatives thereof, to examine records and books of account of, and visit the properties of the Borrower and to discuss the affairs, finances and accounts of the Borrower with any of its officers and directors and with its independent certified public accountants for the purpose of verifying compliance with the representations and covenants made by Borrower hereunder. (c) 936 FUNDS ADVANCES. With respect to any Advance funded at any time with 936 Funds: (i) do all things necessary to be a Qualified Recipient, comply with all requirements and obligations of a Qualified Recipient set forth in Section 936(d)(4) of the Code, the Federal CBI Regulations and the Puerto Rico Regulations, and submit to the Trustee, on each anniversary of the date hereof, a certificate in the form of Exhibit F to the effect that it remains a Qualified Recipient; (ii) promptly after disbursement thereof (and in any event not later than sixty (60) calendar days (30 calendar days in the case of Advances used to replace temporary financings) from the date of disbursement), apply the proceeds of such Advance exclusively to the payment of the 936 Eligible Costs of the Project or to replace temporary financing of such 936 Eligible Costs as permitted under the Federal CBI Regulations, and comply with the temporary investment requirements set forth in the Federal CBI Regulations with respect to the proceeds of such Advances; 28 (iii) notify the Assistant Commissioner (International) of the United States Internal Revenue Service, the Commissioner and the Trustee if it no longer is a Qualified Recipient or if any Advance funded with 936 Funds has ceased to qualify as an Investment in Active Business Assets, promptly upon the occurrence of such disqualifying event; (iv) permit examination by the Office of the Assistant Commissioner (International) of the United States Internal Revenue Service (or by the office of any District Director authorized by the Assistant Commissioner (International)), the Commissioner (or his delegate) and the Trustee of all necessary books and records that are sufficient to verify that the proceeds of such Advance were used to pay 936 Eligible Costs, as required by the terms of this Agreement; (v) submit to the Trustee annually, together with the audited financial statements required pursuant to Section 5.1(a)(i) hereof, an opinion of the independent public accountants that prepared the audited financial statements (A) disclosing the amount of each such Advance, the then current outstanding balance of each such Advance, and a description of the assets financed with the proceeds of each such Advance and the "qualified business activity" (as defined in the Federal CBI Regulations) in which such assets are used, (B) stating that on the basis of the examination of the books and records of the Borrower there are no reasons to doubt that the proceeds of any such Advance have been properly used to pay the 936 Eligible Costs of the Project and continue to be so properly used in accordance with the Puerto Rico Regulations and the Federal CBI Regulations and (C) stating that the interest paid by the Borrower on all Advances constitute foreign source interest income under the general sourcing rules of the Code; (vi) submit to the Trustee promptly upon demand such information as the Trustee shall reasonably request from time to 29 time in order to verify that the proceeds of any such Advance have been, are being or will be properly applied in accordance with the Puerto Rico Regulations and the Federal CBI Regulations and such other information, statements, reports, certificates and documents as may be reasonably requested by the Trustee to comply with the Puerto Rico Regulations and the Federal CBI Regulations; and (vii) submit to the Commissioner on each anniversary of the date hereof a certificate in the form of Exhibit G. SECTION 5.2. NEGATIVE COVENANTS. So long as the Notes shall remain unpaid or CREDIT shall have any Commitment, the Borrower shall not, without the prior written consent of CREDIT: (i) dissolve, (ii) consolidate with or merge into another entity, (iii) sell, dispose, or transfer all or substantially all of the Project or (iv) assign, in whole or in part, this Agreement; provided, however, that, without the consent of CREDIT, the Borrower may consolidate with or merge into another entity, or sell or transfer to another entity all, or substantially all of its assets, or assign in whole or in part this Agreement if (A) the successor or transferee entity: (i) is a Qualified Recipient (and prior to the proposed consolidation, merger, sale or transfer, the Trustee is provided proof reasonably satisfactory to it by the Borrower (which may include an opinion reasonably satisfactory to the Trustee) to that effect); (ii) irrevocably and unconditionally assumes in writing all the obligations of the Borrower herein; and (iii) prior to the proposed consolidation, merger, sale or transfer, the Trustee receives an opinion of tax counsel reasonably satisfactory to it to the effect that immediately following such sale, transfer, assignment, consolidation or merger, the interest on the CREDIT Notes will continue to constitute qualified possession source investment income under Section 936 of the Code and such sale, assignment, transfer, merger or consolidation will not result in an Event of Taxability, and (B) the Borrower has 30 obtained any required consent for such transaction from the Letter of Credit Bank; provided further, however, no sale or other transfer of the Project or assignment of this Agreement without the prior consent of CREDIT shall relieve the Borrower of the obligation to make the payments required hereunder. The Borrower covenants that so long as any CREDIT Notes are outstanding, it will not sell any asset financed with the proceeds of the CREDIT Notes unless (i) the Borrower sells or transfers such asset in the ordinary course of business and (ii) the aggregate original cost of the remaining assets of the Project that qualify as an investment in Active business Assets is greater than or equal to the sum of (A) the aggregate principal amount of the CREDIT Notes outstanding at the time of such sale or transfer and (B) the aggregate principal amount of any other loan funded with "qualified funds" (as such term is used in the Federal CBI Regulations). Any assignment of this Agreement by the Borrower, in whole or in part, is subject to the following additional conditions: (A) the assignee shall, in a certificate delivered to the Trustee, which certificate shall be in a form reasonably satisfactory to the Trustee, (i) expressly assume, and agree to pay and to perform, all of the obligations of the Borrower under this Agreement that shall have been assigned to it and (ii) certify that it qualifies as a Qualified Recipient and that it will continue to comply with the 936 Covenants; and (B) the assignee shall deliver to the Trustee a certificate executed by its chief financial officer, treasurer or a knowledgeable director stating that none of the obligations, covenants and performances under this Agreement assumed by it nor the performance thereof conflicts with, or constitutes on the part 31 of such assignee a breach of, or default under, any indenture, mortgage, agreement or other instrument to which such assignee is a party or by which it is bound, or any existing law, rule, regulation, judgment, order or decree to which such assignee is subject. ARTICLE 6 EVENTS OF DEFAULT SECTION 6.1. EVENTS OF DEFAULT. If any of the following events (each an "Event of Default") shall occur and be continuing: (a) The Borrower shall fail to pay interest within five days after the same becomes due and payable or principal on a Note when the same becomes due and payable; or (b) Any representation or warranty made by the Borrower (or any of its officers) under or in connection with any Loan Document shall prove to have been incorrect in any material respect when made; or (c) The Borrower shall fail to perform or observe any other term, covenant or agreement contained in this Agreement on its part to be performed or observed if such failure shall remain unremedied for thirty (30) days after written notice thereof shall have been given to the Borrower by the Trustee; or (d) The Borrower or the Letter of Credit Bank shall generally not pay its debts as such debts become due, or shall admit in writing its inability to pay its debts generally, or shall make a general assignment for the benefit of creditors; or any proceeding shall be instituted by or against the Borrower or the Letter of Credit Bank seeking to adjudicate it a bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief, or composition of it 32 or its debt under any law relating to bankruptcy, insolvency, receivership or reorganization or relief of debtors, or seeking the entry of an order for relief or the appointment of a receiver, trustee, or other similar official for it or for any substantial part of its property; or the Borrower shall take action to authorize any of the actions set forth above in this subsection (d); or Trinidad & Tobago shall declare a moratorium on the payment of the debts of the Borrower; or (e) Any Governmental Authority or any Person acting under Governmental Authority shall have taken any action to condemn, seize or appropriate, or to assume custody or control of, all or any substantial part of the property of the Borrower (including, without limitation, the Project, or any portion thereof) or shall have taken any action to permanently displace the management of the Borrower or to permanently curtail its authority in the conduct of the business of the Borrower; or (f) The validity of any Loan Document shall be contested by the Borrower or by any legislative, executive or judicial body of Trinidad & Tobago, or the validity of the Letter of Credit shall be contested by the Letter of Credit Bank, or the Borrower shall deny liability under any Loan Document to which it is a party (whether by a general suspension of payments or a moratorium on the payment of Indebtedness or otherwise), or any treaty, law, regulation, communique, decree, ordinance or policy of Trinidad & Tobago shall purport to render any material provision of any Loan Document invalid or unenforceable or shall purport to prevent or materially delay the performance or observance by the Borrower of any of its material obligations under any Loan Document; or (g) The Trustee shall have received a notice of termination of the Letter of Credit or a notice that the Letter of Credit Bank will not reinstate the interest portion of the Letter 33 of Credit, or the Letter of Credit Bank wrongfully fails to honor a draft properly drawn under the Letter of Credit; then, and in any such event, the Trustee (i) may, by notice to the Borrower, declare its obligation to make Advances to be terminated, whereupon the same shall forthwith terminate, and (ii) may, by notice to the Borrower, declare the Advances, all interest thereon and all other amounts payable under this Agreement and any other Loan Document to be forthwith due and payable, whereupon the Advances, all such interest accruing up to the date of payment and all such other amounts shall become and be forthwith due and payable, without presentment, demand, protest or further notice of any kind, all of which are hereby expressly waived by the Borrower; PROVIDED, HOWEVER, that upon the occurrence of any of the events described in subsections (d), (e), (f) and (g) above (A) the obligation to make Advances shall automatically be terminated and (B) all Advances, all Notes, all such interest and all such amounts shall automatically become and be due and payable, without presentment, demand, protest or any notice of any kind, all of which are hereby expressly waived by the Borrower and the Trustee shall immediately make a drawing under the Letter of Credit for the full amount of principal and interest due hereunder. ARTICLE 7 MISCELLANEOUS SECTION 7.1. AMENDMENTS, ETC. No amendment or waiver of any provision of this Agreement, any Note or any of the Loan Documents nor consent to any departure by the Borrower therefrom, shall in any event be effective unless the same shall be in writing and signed by the Trustee, and then such waiver or consent shall be effective only in the specific instance and for the specific purpose for which given. 34 SECTION 7.2. NOTICES. (a) All notices, requests, consents and other communications required or permitted under this Agreement and the other Loan Documents shall be in writing and shall be (as elected by the person giving the notice) hand delivered by messenger or courier service, sent by telecopier, or mailed (airmail if international) by registered or certified mail (postage prepaid), return receipt requested, addressed to: If to the Borrower: Enron Gas & Oil Trinidad Limited Second Floor, The Mutual Centre 16 Queen's Park West Port of Spain Republic of Trinidad & Tobago British West Indies Attn: General Manager Telephone: (809) 622-8653 Telecopier: (809) 628-4218 with copy to: Enron Gas & Oil Trinidad Limited P.O. Box 1188 Houston, Texas 77251-1188 Attn: Walter C. Wilson, Director Telephone: (713) 853-5012 Telecopier: (713) 646-8062 If to the Trustee or CREDIT: Caribbean Regional Development Investment Trust c/o Banco Central Hispano-Puerto Rico, as Trustee 221 Ponce de Leon Avenue Suite 1115 San Juan, Puerto Rico 00919 Attention: Corporate Trust Officer (b) Each such notice shall be deemed delivered (i) on the date delivered with receipt acknowledged if by personal delivery, (ii) on the date of transmission with confirmed receipt if by telecopier, or (iii) on the date upon which the return 35 receipt is signed or delivery is refused or the notice is designated by the postal authorities as not deliverable, as the case may be, if mailed. (c) By giving to the other party at least fifteen (15) days written notice thereof, such party and its successors and assigns shall have the right from time to time and at any time during the term of this Agreement to change their respective addresses. SECTION 7.3. NO WAIVER; REMEDIES. No failure on the part of the Trustee to exercise, and no delay in exercising, any right under this Agreement, any Note or any other Loan Document shall operate as a waiver thereof, nor shall any single or partial exercise of any such right preclude any other or further exercise thereof or the exercise of any other right. The remedies herein provided are cumulative and not exclusive of any remedies provided by law. SECTION 7.4. ACCOUNTING TERMS; CURRENCY EQUIVALENT. All accounting terms not specifically defined herein shall be construed in accordance with United States generally accepted accounting principles consistently applied, except as otherwise stated herein. For purposes of construction of the terms hereof, the equivalent in another currency of an amount in Dollars shall be determined by using the quoted spot rate at which Citibank, N.A.'s principal office in New York City offers to purchase such other currency with the equivalent in Dollars in New York City at 9:00 a.m. (New York City time) on the date on which such equivalent is to be determined. SECTION 7.5. COSTS AND EXPENSES; INDEMNIFICATION. (a) The Borrower agrees to (i) reimburse CREDIT from time to time on request for its reasonable out-of-pocket costs and expenses (including, without limitation, printing, reproduction, document 36 delivery, travel costs, and legal fees (such legal fees not to exceed U.S. $80,000) and expenses) incurred in connection with the preparation, review, negotiation, execution, delivery and administration of this Agreement, each Note, all other Loan Documents and the other documents to be delivered hereunder; (ii) pay from time to time upon request all costs and expenses (including reasonable fees and expenses of legal counsel) in connection with the enforcement by CREDIT of this Agreement, each Note, all other Loan Documents and the other documents to be delivered hereunder; (iii) to pay Citibank, N.A. directly a structuring and servicing fee equal to 3/8 of 1% per annum of the principal amount of each Advance outstanding from time to time computed on the basis of actual days and a year of 365/366 days, such payment to be made on each Interest Payment Date; (iv) to pay the fees of the Trustee equal to .05% per annum payable on each Interest Payment Date; and (v) to pay a one-time fee to Caribbean Basin Project Financing Authority equal to .25% of the principal amount of each Advance, such fee being payable on the Closing Date. (b) The Borrower agrees, to the fullest extent permitted by law, to indemnify and hold harmless Citicorp Financial Services Corporation, CREDIT, the Trustee and each of their respective affiliates, directors, officers, stockholders and employees (each an "Indemnified Party"), from and against any and all claims, damages, liabilities and expenses (including without limitation, reasonable fees and disbursements of counsel) for which any of them may become liable or which may be incurred by or asserted against any of them, in each case in connection with or arising out of or by reason of any investigation, litigation, or proceeding, whether or not an Indemnified Party is a party thereto, arising out of, related to or in connection with this Agreement or any other Loan Document or any transaction in which any proceeds of all or any part of the Advances are applied (other than any such claim, damage, liability or expense attributable to the gross negligence or willful misconduct of such Indemnified Party). 37 (c) Without limiting the generality of other indemnities set forth elsewhere in this Agreement, the Borrower agrees upon demand, to indemnify and hold harmless the Trustee, CREDIT and each holder of the CREDIT Notes against and from all "936 Indemnity Losses" (as defined hereinbelow) arising at any time now or hereafter by reason of any of the following: (i) any act of commission or omission by the Borrower; (ii) any breach of any covenant, representation, warranty, acknowledgment or statement by the Borrower contained in this Agreement or in any certificate or other written statement provided in connection herewith; (iii) any adverse determination made by the United States Internal Revenue Service, the Commissioner or any Governmental Authority in the United States or the Commonwealth as to the qualification of any of the Advances or any transactions related thereto as an Eligible Activity or an Investment in Active Business Assets under Section 936 of the Code, the Federal CBI Regulations or the Puerto Rico Regulations; (iv) any failure by the Borrower to permit the Trustee to discharge or fulfill its duties or obligations under the Puerto Rico Regulations or the Federal CBI Regulations; or (v) any change to Section 936 of the Code or the regulations thereunder or in the interpretation thereof, that results in any adverse consequence to CREDIT and/or a holder of a CREDIT Note due to any Advance funded with 936 Funds being outstanding; provided, however, an indemnity under this clause (v) shall be limited to the excess of the actual "936 Indemnity Losses" over the amount of any interest rate adjustment resulting from a "Change in Tax Law" as described in Section 2.6. 38 For purposes of this subsection, "936 Indemnity Losses" shall mean and include any taxes (plus interest assessed thereon), cost, damage, liability, fine, penalty, claim, cause of action, judgment, court cost and legal or other expense, including attorneys' fees, relating directly or indirectly to Section 936 of the Code, the Federal CBI Regulations or the Puerto Rico Regulations. (d) The obligations set forth in this Section 7.5 shall survive the repayment in full of the Advances and the termination of this Agreement for a period of five years thereafter. SECTION 7.6. JUDGMENT. (a) If for the purposes of obtaining judgment in any court it is necessary to convert a sum due hereunder or under a Note in Dollars into another currency, the parties hereto agree, to the fullest extent that they may effectively do so, that the rate of exchange used shall be the best available exchange rate at which in accordance with normal banking procedures CREDIT could purchase Dollars with such other currency on the Business Day preceding that on which final judgment is given. (b) The obligation of the Borrower in respect of any sum due from it to CREDIT hereunder or under any Note shall, notwithstanding any judgment in a currency other than Dollars, be discharged only to the extent that on the Business Day following receipt by CREDIT of any sum adjudged to be so due in such other currency CREDIT, may in accordance with normal banking procedures and using the best available exchange rate purchase Dollars with such other currency; if the Dollars so purchased are less than the sum due or adjudged to be so due to CREDIT in Dollars, the Borrower agrees, as a separate obligation and notwithstanding any such judgment, to indemnify CREDIT, against such loss, and if the Dollars so purchased exceed the sum due or adjudged to be due to 39 CREDIT in Dollars, CREDIT agrees to remit to the Borrower such excess. SECTION 7.7. CONSENT TO JURISDICTION; WAIVER OF IMMUNITIES. (a) The Borrower hereby irrevocably submits to the jurisdiction of any Commonwealth of Puerto Rico or Federal court sitting in San Juan, Puerto Rico and any appellate court thereof in any action or proceeding arising out of or relating to this Agreement, any Note or any other Loan Document, and the Borrower hereby irrevocably agrees that all claims in respect of such action or proceeding may be heard and determined in such Commonwealth of Puerto Rico court or in such Federal court. The Borrower hereby irrevocably waives, to the fullest extent it may effectively do so, the defense of an inconvenient forum to the maintenance of such action or proceeding. The Borrower hereby irrevocably appoints CT Corporation System (the "Process Agent"), with an office on the date hereof at 361 San Francisco Street, Penthouse, Old San Juan, Puerto Rico 00901, as its agent to receive on behalf of the Borrower and its property service of copies of the summons and complaint and any other process which may be served in any such action or proceeding. Such service may be made by mailing or delivering a copy of such process to the Borrower in care of the Process Agent at the Process Agent's above address, and the Borrower hereby irrevocably authorizes and directs the Process Agent to receive and forward such service on its behalf. As an alternative method of service, the Borrower also irrevocably consents to the service of any and all process in any such action or proceeding by the mailing of copies of such process to the Borrower at its address specified in Section 7.2. The Borrower agrees that a final judgment in any such action or proceeding shall be conclusive and may be enforced in other jurisdictions by suit on the judgment or in any other manner provided by law. (b) Nothing in this Section 7.7 shall affect the right of CREDIT to serve legal process in any other manner permitted by 40 law or affect the right of CREDIT to bring any action or proceeding against the Borrower or its property in the courts of other jurisdictions. (c) To the extent that the Borrower has or hereafter may acquire sovereign immunity from jurisdiction of any court or from any legal process (whether through service or notice, attachment prior to judgment, attachment in aid of execution, execution or otherwise) with respect to itself or its property, the Borrower to the fullest extent it may lawfully do so hereby irrevocably waives such sovereign immunity in respect of its obligations under this Agreement, any Note or any other Loan Document, and, without limiting the generality of the foregoing, agrees that the waivers set forth in this subsection (c) shall have the fullest scope permitted under the Foreign Sovereign Immunities Act of 1976 of the United States and are intended to be irrevocable for purposes of such Act. SECTION 7.8. BINDING EFFECT. This Agreement shall be binding upon and inure to the benefit of the Borrower and CREDIT and their respective successors and permitted assigns, except that the Borrower shall not have the right to assign its rights hereunder or any interest herein without the prior written consent of CREDIT other than as permitted in Section 5.2. SECTION 7.9. GOVERNING LAW. This Agreement and each Note shall be governed by, and construed in accordance with, the laws of the Commonwealth of Puerto Rico. CREDIT and the Borrower hereby acknowledge that the selection of the Commonwealth of Puerto Rico law as the governing law in this Agreement and each Note has been made bona fide and legally on sound commercial principles that are customary in such agreements, and not for the purpose of evading the provisions of any legal system with which any of said documents may be said to be objectively connected. 41 SECTION 7.10. EXECUTION IN COUNTERPARTS. This Agreement may be executed in any number of counterparts and by different parties hereto in separate counterparts, each of which when so executed shall be deemed to be an original and all of which taken together shall constitute but one and the same agreement. SECTION 7.11. LIMITATION ON INTEREST. No provision of this Agreement or any Note shall require the payment or permit the collection of interest in excess of the maximum rate permitted by applicable law. SECTION 7.12. SALE OF NOTE, PARTICIPATIONS AND COMMITMENTS. CREDIT may, at any time, without the consent of the Borrower, sell, assign or otherwise dispose of its Notes and Advances, or of participations therein, or of all or any portion of its rights under any Loan Document, to any Eligible Institution. The Borrower hereby agrees to execute any and all documents that CREDIT may reasonably request in order to effectuate any foregoing action permitted to CREDIT. Borrower shall be provided written notice of such assignment within ten days of the date it is made. No such assignment shall be made unless prior thereto the assignee shall have executed a confidentiality agreement with the Borrower substantially similar to the one executed by Citicorp Financial Services Corporation. If notice of such assignment is provided within fifteen (15) days from an Interest Payment Date, Borrower reserves the right to pay the interest due on such immediately occurring Interest Payment Date to the assignor. SECTION 7.13. SEVERABILITY OF PROVISIONS. Any provision of this Agreement which is prohibited or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof or affecting the validity or enforceability of such provision in any other jurisdiction. 42 IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be executed by their respective officers or agents thereunto duly authorized, as of the date first above written. ENRON GAS & OIL TRINIDAD LIMITED By: CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: EXHIBIT A PROMISSORY NOTE U.S. $ Dated as of: , 199 FOR VALUE RECEIVED, the undersigned, ENRON GAS & OIL TRINIDAD LIMITED, a company organized and existing under the laws of Trinidad & Tobago (the "Borrower"), HEREBY PROMISES TO PAY to the order of CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST (the "Lender") for the account of its Lending Office (as defined in the Credit Agreement referred to below) the principal sum of UNITED STATES DOLLARS U.S. $ ). The Borrower agrees to pay interest on the unpaid principal amount hereof from the date hereof until such principal amount is paid in full, at such interest rates, and payable at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to the Lender at its Lending Office (as defined in the Credit Agreement), in same day funds, free and clear of and without deduction for any and all present and future Taxes as set forth in the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is entitled to the benefits and guaranties of, the Credit Agreement dated as of March 8, 1994 (the "Credit Agreement"), between the Borrower and the Lender. The Credit Agreement, among other things, (i) provides for the making of advances (the "Advances") by the Lender to Borrower from time to time, the indebtedness of the Borrower resulting from one such Advance being evidenced by this Promissory Note, and (ii) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. The parties hereto, including the makers and endorsers of this Promissory Note, hereby waive protest and severally agree that the holder of this Promissory Note may extend the time of payment, or release any collateral held, with or without notice to all or to any of the parties hereto, and that thereafter all parties hereto will remain liable hereon, as if they, and each of them, has expressly consented to such extension or release. The undersigned hereby waives presentment, demand and notice of non-payment. The undersigned acknowledges receipt of a true and exact copy of this Promissory Note. 2 This Note shall be governed by, and construed in accordance with, the laws of the Commonwealth of Puerto Rico. ENRON GAS & OIL TRINIDAD LIMITED By: Name: Title: EXHIBIT B ITEMS OF PROJECT COSTS ELIGIBLE FOR 936 FUNDS FINANCING EXHIBIT C OPINION OF COUNSEL FOR THE BORROWER {Date of initial Advance} Caribbean Regional Development Investment Trust 221 Ponce de Leon Avenue Hato Rey San Juan, Puerto Rico Re: U.S. $75,000,000 - Credit Facility to Enron Gas & Oil Trinidad Limited Ladies and Gentlemen: This opinion is furnished to you pursuant to Section 3.1(xi) of the Credit Agreement dated as of March 8, 1994, (the "Credit Agreement") between Enron Gas & Oil Trinidad Limited (the "Borrower") and you. Unless otherwise indicated terms defined in the Credit Agreement are used herein as therein defined. We have acted as counsel for the Borrower in connection with the preparation, execution and delivery of, and the initial Advance made under, the Credit Agreement. In that connection we have examined: (1) The Credit Agreement; (2) The Notes evidencing the two initial Advances and the form of Note attached as Exhibit A to the Credit Agreement; (3) The Memorandum and Articles of Association of the Borrower, as amended to date (the "Articles of Association"); (4) Such other documents, agreements and instruments, and such laws, rules, regulations, orders, decrees, writs, judgments, awards, injunctions, and the like, as we have deemed necessary as a basis for the opinions hereinafter expressed. Our opinion set forth below must be read subject to the following observations: I. We express no opinion as to any law other than the laws of Trinidad & Tobago as presently existing. In particular we express no opinion as to any aspect of the laws of the Commonwealth 2 of Puerto Rico which as set forth in paragraph (l) below, is, in our opinion, the law governing the Credit Agreement and the Notes. II. For the purpose of this opinion we have assumed that the Credit Agreement and the Notes are in proper legal form under the laws of the Commonwealth of Puerto Rico for the enforcement thereof against the Borrower under the laws of the Commonwealth of Puerto Rico. III. For the purpose of this opinion, we have also assumed that the selection of law as set out in the Credit Agreement has been made bona fide and legally and that the choice was not made expressly to evade the provisions of the legal system with which the said document objectively is connected. In fact, we have been advised that such choice was made bona fide and legally on sound commercial principles which are customary in such agreements. IV. The validity and enforceability of the Credit Agreement may be limited by bankruptcy, insolvency, reorganization, moratorium, liquidation, probate, conservatorship, any other similar laws (including court decisions) now or hereafter in effect and affecting the rights of creditors generally. V. The opinions expressed herein are as of the date hereof only, and we assume no obligation to update or supplement such opinions to reflect any fact or circumstances that may hereafter occur or become effective. Based upon the foregoing and upon such investigation as we have deemed necessary, we are of the opinion that: (a) The Borrower is a limited liability company duly organized, validly existing and in good standing under the laws of Trinidad & Tobago. (b) The execution, delivery and performance by the Borrower of the Credit Agreement and the Notes are within the Borrower's corporate powers, have been duly authorized by all necessary corporate action, and do not contravene (i) the Borrower's Articles of Association, (ii) any treaty, law, rule, regulation, order, decree, writ, judgment, award, injunction or similar legal restriction of Trinidad & Tobago applicable to the Borrower and its properties or (iii) to the best of our knowledge after due inquiry, any contractual restriction contained in any indenture, loan or credit agreement, guaranty, debenture, mortgage, deed of trust, bond, note, or other agreement or instrument that binds or affects or purports to bind or affect the Borrower and its properties. The Credit Agreement and the Notes have been duly executed on behalf of the Borrower. 3 (c) No authorization or approval (including exchange control approval) or other action by, and no notice to or filing with, any Governmental Authority or regulatory body is required for the due execution, delivery and performance by the Borrower of the Credit Agreement or any Note. (d) The Credit Agreement and the Notes are, or will be when executed pursuant to the provisions of the Credit Agreement, the legal, valid and binding obligations of the Borrower enforceable against the Borrower in accordance with their respective terms. (e) The obligations of the Borrower under the Credit Agreement and the Notes rank at least PARI PASSU in priority of payment and in all other respects with all other Indebtedness of the Borrower. (f) There is no pending or, to the best of our knowledge after due inquiry, threatened action or proceeding involving the Borrower before any court, Governmental Authority or arbitrator that may materially adversely affect the financial condition or operations of the Borrower or that purports to affect the legality, validity or enforceability of the Credit Agreement or the Notes. (g) The Borrower is subject to civil and commercial law with respect to its obligations under the Credit Agreement and the Notes, and the execution, delivery and performance of the Credit Agreement and the Notes constitute private and commercial acts rather than public or governmental acts. Neither the Borrower nor any of its property has any immunity from jurisdiction of any court or from set-off or any legal process (whether through service or notice, attachment prior to judgment, attachment in aid of execution, execution or otherwise) under the laws of Trinidad & Tobago. The waiver of immunities, the submission to the jurisdiction of the Commonwealth of Puerto Rico and Federal courts sitting in San Juan, Puerto Rico, and the appointment of the Process Agent, contained in Section 7.7 of the Credit Agreement, are irrevocably binding on the Borrower. (h) There is no tax, levy, impost, deduction, charge or withholding tax, except for the withholding tax of .001% on interest payments, imposed or assessable by Trinidad & Tobago or any political subdivision, taxing authority or Governmental Authority thereof or therein either (i) on or by virtue of the execution or delivery of the Credit Agreement or the Notes, or (ii) on any payment to be made by the Borrower pursuant to the Credit Agreement or the Notes. (i) It is not necessary that the Credit Agreement or the Notes be filed or recorded with any court or other authority in Trinidad & Tobago or that any stamp or similar tax be paid on or in respect of the Credit Agreement or the Notes for the enforcement thereof against the Borrower under the laws of Trinidad & Tobago. 4 (j) The interest and the fees and charges required to be paid under the Notes and the Credit Agreement are not usurious or otherwise illegal under the laws of Trinidad & Tobago. (k) The Credit Agreement and the Notes are in proper legal form under the laws of Trinidad & Tobago for the enforcement thereof against the Borrower under the laws of Trinidad & Tobago. (l) In any action or proceeding arising out of or relating to the Credit Agreement and the Notes in any court in Trinidad & Tobago such court would recognize and give effect to the provisions of Section 7.9 of the Credit Agreement wherein the parties thereto agree that the Credit Agreement and the Notes shall be governed by, and construed in accordance with, the laws of the Commonwealth of Puerto Rico. (m) It is not necessary under the laws of Trinidad & Tobago (i) in order to enable the Lender to enforce its rights under the Credit Agreement and the Notes or (ii) by reason of the execution, delivery or performance of the Credit Agreement, that it should be licensed, qualified or entitled to carry on business in Trinidad & Tobago. (n) The Lender is not and will not be resident, domiciled, carrying on business or subject to taxation in Trinidad & Tobago by reason only of the execution, delivery, performance or enforcement of the Credit Agreement or the Notes. (o) A judgment rendered by any Commonwealth of Puerto Rico or Federal court sitting in San Juan, Puerto Rico in respect of the Credit Agreement or the Notes would be enforceable against the Borrower in the courts of Trinidad & Tobago. This opinion may be relied upon by you and your assigns in connection with the Credit Agreement and the transactions contemplated thereby and may not be used for any other purpose or relied upon by any other person. Neither its contents nor its existence may be disclosed without our prior written consent. Very truly yours, M HAMEL-SMITH & CO. By: Philip Hamel-Smith EXHIBIT D {Letterhead of Process Agent} Date: March , 1994 Caribbean Regional Development Investment Trust 221 Ponce de Leon Avenue Hato Rey, San Juan, Puerto Rico Re: United States $75,00,000 - Credit Facility to Enron Gas & Oil Trinidad Limited Ladies and Gentlemen: Reference is made to that certain Credit Agreement dated as of March 8, 1994 (said Agreement, as it may hereafter be amended, supplemented or otherwise modified from time to time, being the "Credit Agreement", the terms defined therein being used herein with the same meaning) between Enron Gas & Oil Trinidad Limited (the "Borrower") and you. Pursuant to Section 7.7(a) of the Credit Agreement the Borrower has appointed the undersigned (with an office on the date hereof at 361 San Francisco Street, Penthouse, Old San Juan, Puerto Rico 00901) as Process Agent to receive on behalf of the Borrower and its property service of copies of the summons and complaint and any other process that may be served in any action or proceeding in any Commonwealth of Puerto Rico or Federal court sitting in San Juan, Puerto Rico arising out of or relating to the Credit Agreement, the Notes issued pursuant thereto, and any other Loan Document executed pursuant thereto. The undersigned hereby accepts such appointment as Process Agent and agrees with you that (i) the undersigned will not terminate the undersigned's agency as such Process Agent prior to March 8, 1999 (and hereby acknowledges that the undersigned has been paid in full by the Borrower for its services as Process Agent through such date), (ii) the undersigned will maintain an office in San Juan, Puerto Rico through such date and will give you prompt notice of any change of address of the undersigned, (iii) the undersigned will perform its duties as Process Agent in accordance with Section 7.7(a) of the Credit Agreement and (iv) the undersigned will forward forthwith to the Borrower at its address specified in Section 7.2 of the Credit Agreement copies of any 2 summons, complaint and other process that the undersigned receives in connection with its appointment as Process Agent. This acceptance and agreement shall be binding upon the undersigned and all successors of the undersigned. Very truly yours, CT CORPORATION SYSTEM By: EXHIBIT E REQUEST FOR ADVANCE No. Caribbean Regional Development Investment Trust 221 Ponce de Leon Avenue Suite 1115 Hato Rey, San Juan, Puerto Rico Re: U.S. $75,000,000 - Credit Facility to Enron Gas & Oil Trinidad Limited Ladies and Gentlemen: Reference is made to that certain Credit Agreement, dated as of March 8, 1994, between Enron Gas & Oil Trinidad Limited (the "Borrower") and Caribbean Regional Development Investment Trust ("CREDIT") (the "Credit Agreement"). Terms defined in the Credit Agreement are used herein as therein defined. Pursuant to Section 3.2(a)(i) of the Credit Agreement, the undersigned hereby requests an Advance, the proceeds of which will be disbursed by the Borrower within { } calendar days after the date of the Advance, as follows: NAME AND ADDRESS OF PERSON GENERAL TO WHOM BORROWER WILL PAY THE AMOUNT DESCRIPTION ITEM NUMBER PROCEEDS OF THE ADVANCE OF PAYMENT OF ITEM With respect to the amount hereby requisitioned to be paid, the Borrower hereby certifies that: (a) Each obligation for which payment is requested in this Request for Advance (i) has been properly incurred or will be incurred by Borrower within the next { ( )} calendar days, (ii) is now due or will be due and payable in full within the next ( ) calendar days to the Person(s) listed above, and (iii) constitutes a 936 Eligible Cost. No part of such amount has been or is being made the basis of Requests for Advance in any previous or now pending Request for Advance, or has been paid out of the proceeds of insurance received by Borrower. (b) The total of the amounts heretofore paid and to be paid pursuant to previous Requests for Advance and to be paid pursuant to this Request have been applied to pay 936 Eligible Costs of the Project that are properly subject to payment under the Credit Agreement. 2 (c) The amount of the Advance now requested either has been paid by Borrower or is justly due to vendors, suppliers, contractors, subcontractors, materialmen, or other Persons (whose names and addresses are stated in this requisition) who have rendered services or furnished materials for the Project. Borrower agrees that the Advance to be made hereunder shall be payable on the Maturity Date set forth below and shall bear interest at the following rate: Fixed: % Floating: % of the LIBID Rate Maturity Date: IN WITNESS WHEREOF, the undersigned has caused this Request for Advance to be executed and delivered on this day of , 1994. ENRON GAS & OIL TRINIDAD LIMITED By: Name: Title: ACCEPTED BY CREDIT: By: Name: Title: Date: EXHIBIT F CERTIFICATION AS TO QUALIFIED RECIPIENT STATUS REQUIRED BY TREAS. REG. SECTION 1.936-10(c)(11)(i) {LETTERHEAD OF BORROWER} March , 1994 Caribbean Regional Development Investment Trust 252 Ponce de Leon Avenue Hato Rey San Juan, Puerto Rico Ladies and Gentlemen: The undersigned, Enron Gas & Oil Trinidad Limited (the "Borrower"), refers to the Credit Agreement, dated as of March 8, 1994 (the "Credit Agreement"), by and between Borrower and Caribbean Regional Development Investment Trust (the "Lender"), as the same may be amended or supplemented from time to time. Unless otherwise indicated, terms defined in the Credit Agreement are used herein as therein defined. Borrower hereby represents and warrants that: 1. It is a limited liability company duly organized, validly existing and in good standing under the laws of Trinidad & Tobago. 2. It is currently engaged in the development of oil and gas fields off the coast of Trinidad & Tobago. 3. It is a Qualified Recipient under the Federal CBI Regulations. 4. {It has used all 936 Funds borrowed under the Credit Agreement exclusively for an Investment in Active 2 Business Assets and has complied with all 936 Covenants of the Credit Agreement.}* Very truly yours, ENRON GAS & OIL TRINIDAD LIMITED By: * To be included in each annual certification required by the Credit Agreement. EXHIBIT G CERTIFICATE REQUIRED UNDER SECTION 6.4.3(a)(iii) OF REGULATION 3582 PLEASE READ BEFORE SIGNING The undersigned hereby acknowledges that, prior to the granting of the loan referred to below, it was aware that the loan would be as an eligible activity for use of 936 Funds. ENRON GAS & OIL TRINIDAD LIMITED By: Name: Title: Date: March 8, 1994 The following three sections should be filled out by the Financial Institution: 1. Purpose of the loan: To finance the cost of developing off shore platforms, drilling wells and installing pipelines. 2. Collateral: Credit Suisse Letter of Credit. 3. Amount: $31,000,000 4. Date: March 8, 1994 CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: EXHIBIT H FORM OF CERTIFICATION REQUIRED BY TREAS. REG. SECTION 1.936-10(c)12 March 8, 1994 Assistant Commissioner (International) Internal Revenue Service Office of Taxpayer Service and Compliance 950 L'Enfant Plaza South, S.W. Washington, D.C. 20024 Commissioner of Financial Institutions PO Box 70324 San Juan, Puerto Rico 00936-0324 Ladies and Gentlemen: The undersigned, Caribbean Regional Development Investment Trust (the "Lender") and Enron Gas & Oil Trinidad Limited (the "Borrower"), refer to the Credit Agreement, dated as of March 8, 1994 (the "Credit Agreement") by and between Lender and Borrower, as the same may be amended or supplemented from time to time. As required by the Treasury Regulation Section 1.936-10(c)(12) (the "Federal CBI Regulations") and Regulation 5002 issued by the Commissioner of Financial Institutions of the Commonwealth of Puerto Rico, Borrower and Lender hereby certify that: 1. Borrower has complied with the requirements of paragraph (c)(11) of the Federal CBI Regulations. 2. Under the Credit Agreement, the Lender has agreed to lend Borrower up to U.S. $75,000,000 (the "Loan") to finance (or refinance or replace with 936 Funds as permitted by paragraphs (c)(7)(i) and (c)(7)(ii) of the Federal CBI Regulations) the costs (qualifying as capital expenditures under the Federal CBI Regulations) incurred in connection with the construction of off-shore platforms, laying of pipelines and drilling of oil and gas wells off the coast of Trinidad & Tobago. 3. The Borrower is a limited liability company duly organized validly existing and in good standing under the laws of Trinidad & Tobago. The Borrower is an indirect wholly-owned subsidiary of Enron Oil & Gas Company. -2- 4. The loan is guaranteed by a letter of credit issued by Credit Suisse. 5. We hereby agree to permit you (or your authorized representative) to examine all necessary books and records that are sufficient to verify that the 936 Funds provided by the Lender were used for Investments in Active Business Assets (as defined in the Federal CBI Regulations) in conformity with the terms of the Credit Agreement. Very truly yours, ENRON GAS & OIL TRINIDAD LIMITED By: CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: -3- REQUEST FOR ADVANCE No. 1 Caribbean Regional Development Investment Trust 221 Ponce de Leon Avenue Suite 1115 Hato Rey, San Juan, Puerto Rico Re: U.S. $75,000,000 - Credit Facility to Enron Gas & Oil Trinidad Limited Ladies and Gentlemen: Reference is made to that certain Credit Agreement, dated as of March 8, 1994, between Enron Gas & Oil Trinidad Limited (the "Borrower") and Caribbean Regional Development Investment Trust ("CREDIT") (the "Credit Agreement"). Terms defined in the Credit Agreement are used herein as therein defined. Pursuant to Section 3.2(a)(i) of the Credit Agreement, the undersigned hereby requests an Advance in the amount of $16,000,000, the proceeds of which will be applied by the Borrower immediately (together with Advance No. 2) to repay $31,000,000 principal amount of the bridge loan provided by Citibank, N.A. for the financing of the Project. With respect to the amount hereby requisitioned to be paid, the Borrower hereby certifies that: (a) Each obligation for which payment is requested in this Request for Advance constitutes a 936 Eligible Cost. No part of such amount has been or is being made the basis of Requests for Advance in any previous or now pending Request for Advance, or has been paid out of the proceeds of insurance received by Borrower. (b) The total of the amounts to be paid pursuant to this Request have been applied to pay 936 Eligible Costs of the Project that are properly subject to payment under the Credit Agreement. Borrower agrees that the Advance to be made hereunder shall be payable on the Maturity Date set forth below and shall bear interest at the following rate: Fixed: 4.52% Floating: N/A Maturity Date: May 1, 1998 -4- IN WITNESS WHEREOF, the undersigned has caused this Request for Advance to be executed and delivered on this 4th day of March, 1994. ENRON GAS & OIL TRINIDAD LIMITED By: Name: W. C. Wilson Title: Director ACCEPTED BY CREDIT: By: Name: Title: Date: -1- REQUEST FOR ADVANCE No. 2 Caribbean Regional Development Investment Trust 221 Ponce de Leon Avenue Suite 1115 Hato Rey, San Juan, Puerto Rico Re: U.S. $75,000,000 - Credit Facility to Enron Gas & Oil Trinidad Limited Ladies and Gentlemen: Reference is made to that certain Credit Agreement, dated as of March 8, 1994, between Enron Gas & Oil Trinidad Limited (the "Borrower") and Caribbean Regional Development Investment Trust ("CREDIT") (the "Credit Agreement"). Terms defined in the Credit Agreement are used herein as therein defined. Pursuant to Section 3.2(a)(i) of the Credit Agreement, the undersigned hereby requests an Advance in the amount of $15,000,000, the proceeds of which will be applied by the Borrower immediately (together with Advance No. 1) to repay $31,000,000 principal amount of the bridge loan provided by Citibank, N.A. for the financing of the Project. With respect to the amount hereby requisitioned to be paid, the Borrower hereby certifies that: (a) Each obligation for which payment is requested in this Request for Advance constitutes a 936 Eligible Cost. No part of such amount has been or is being made the basis of Requests for Advance in any previous or now pending Request for Advance, or has been paid out of the proceeds of insurance received by Borrower. (b) The total of the amounts to be paid pursuant to this Request have been applied to pay 936 Eligible Costs of the Project that are properly subject to payment under the Credit Agreement. Borrower agrees that the Advance to be made hereunder shall be payable on the Maturity Date set forth below and shall bear interest at the following rate: Fixed: N/A Floating: 84% of the LIBID Rate Maturity Date: May 1, 1998 -2- IN WITNESS WHEREOF, the undersigned has caused this Request for Advance to be executed and delivered on this 4th day of March, 1994. ENRON GAS & OIL TRINIDAD LIMITED By: Name: W. C. Wilson Title: Director ACCEPTED BY CREDIT: By: Name: Title: Date: EX-10.41 16 PROMISSORY NOTE EXHIBIT 10.41 PROMISSORY NOTE U.S. $15,000,000 Dated as of: March 8, 1994 FOR VALUE RECEIVED, the undersigned, ENRON GAS & OIL TRINIDAD LIMITED, a company organized and existing under the laws of Trinidad & Tobago (the "Borrower"), HEREBY PROMISES TO PAY to the order of CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST (the "Lender") for the account of its Lending Office (as defined in the Credit Agreement referred to below) the principal sum of FIFTEEN MILLION UNITED STATES DOLLARS (U.S. $15,000,000). The Borrower agrees to pay interest on the unpaid principal amount hereof from the date hereof until such principal amount is paid in full, at such interest rates, and payable at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to the Lender at its Lending Office (as defined in the Credit Agreement), in same day funds, free and clear of and without deduction for any and all present and future Taxes as set forth in the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is entitled to the benefits and guaranties of, the Credit Agreement dated as of March 8, 1994 (the "Credit Agreement"), between the Borrower and the Lender. The Credit Agreement, among other things, (i) provides for the making of advances (the "Advances") by the Lender to Borrower from time to time, the indebtedness of the Borrower resulting from one such Advance being evidenced by this Promissory Note, and (ii) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. The parties hereto, including the makers and endorsers of this Promissory Note, hereby waive protest and severally agree that the holder of this Promissory Note may extend the time of payment, or release any collateral held, with or without notice to all or to any of the parties hereto, and that thereafter all parties hereto will remain liable hereon, as if they, and each of them, has expressly consented to such extension or release. The undersigned hereby waives presentment, demand and notice of non-payment. The undersigned acknowledges receipt of a true and exact copy of this Promissory Note. 2 This Note shall be governed by, and construed in accordance with, the laws of the Commonwealth of Puerto Rico. ENRON GAS & OIL TRINIDAD LIMITED By: Name: W. C. Wilson Title: Director EX-10.42 17 PROMISSORY NOTE EXHIBIT 10.42 PROMISSORY NOTE U.S. $16,000,000 Dated as of: March 8, 1994 FOR VALUE RECEIVED, the undersigned, ENRON GAS & OIL TRINIDAD LIMITED, a company organized and existing under the laws of Trinidad & Tobago (the "Borrower"), HEREBY PROMISES TO PAY to the order of CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST (the "Lender") for the account of its Lending Office (as defined in the Credit Agreement referred to below) the principal sum of SIXTEEN MILLION UNITED STATES DOLLARS (U.S. $16,000,000). The Borrower agrees to pay interest on the unpaid principal amount hereof from the date hereof until such principal amount is paid in full, at such interest rates, and payable at such times, as are specified in the Credit Agreement. Both principal and interest are payable in lawful money of the United States of America to the Lender at its Lending Office (as defined in the Credit Agreement), in same day funds, free and clear of and without deduction for any and all present and future Taxes as set forth in the Credit Agreement. This Promissory Note is one of the Notes referred to in, and is entitled to the benefits and guaranties of, the Credit Agreement dated as of March 8, 1994 (the "Credit Agreement"), between the Borrower and the Lender. The Credit Agreement, among other things, (i) provides for the making of advances (the "Advances") by the Lender to Borrower from time to time, the indebtedness of the Borrower resulting from one such Advance being evidenced by this Promissory Note, and (ii) contains provisions for acceleration of the maturity hereof upon the happening of certain stated events and also for prepayments on account of principal hereof prior to the maturity hereof upon the terms and conditions therein specified. The parties hereto, including the makers and endorsers of this Promissory Note, hereby waive protest and severally agree that the holder of this Promissory Note may extend the time of payment, or release any collateral held, with or without notice to all or to any of the parties hereto, and that thereafter all parties hereto will remain liable hereon, as if they, and each of them, has expressly consented to such extension or release. The undersigned hereby waives presentment, demand and notice of non-payment. The undersigned acknowledges receipt of a true and exact copy of this Promissory Note. 2 This Note shall be governed by, and construed in accordance with, the laws of the Commonwealth of Puerto Rico. ENRON GAS & OIL TRINIDAD LIMITED By: Name: W. C. Wilson Title: Director EX-10.43 18 LETTER OF CREDIT AND REIMBURSEMENT AGREEMENT EXHIBIT 10.43 LETTER OF CREDIT AND REIMBURSEMENT AGREEMENT between ENRON GAS & OIL TRINIDAD LIMITED, and CREDIT SUISSE, a Swiss banking corporation, acting through its New York Branch March 8, 1994 INDEX Page INTRODUCTION . . . . . . . . . . . . . . . . . . . . . . . . . . 1 ARTICLE I . . . . . . . . . . . . 1 DEFINITIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 1.1 Defined Terms . . . . . . . . . . . . . . . . . . . . . 1 1.2 Other Definitional Provisions . . . . . . . . . . . . . 4 1.3 Accounting Terms . . . . . . . . . . . . . . . . . . . 4 ARTICLE II . . . . . . . . . . . . 4 LETTER OF CREDIT FACILITY AND OPERATIONS . . . . . . . . . . . . 4 2.1 Request for Issuance of Letter of Credit . . . . . . . 4 2.2 Notice of Drawings . . . . . . . . . . . . . . . . . . 4 ARTICLE III . . . . . . . . . . . . 4 REIMBURSEMENT AND PAYMENT OBLIGATIONS . . . . . . . . . . . . . . 4 3.1 Reimbursement and Payment Obligations . . . . . . . . . 4 3.2 Cash Collateral Account . . . . . . . . . . . . . . . . 8 3.3 Illegality . . . . . . . . . . . . . . . . . . . . . . 9 3.4 Method of Payment . . . . . . . . . . . . . . . . . . . 9 ARTICLE IV . . . . . . . . . . . . 9 CONDITIONS PRECEDENT TO ISSUANCE OF LETTER OF CREDIT . . . . . . 9 4.1 Guaranty . . . . . . . . . . . . . . . . . . . . . . . 9 4.2 Resolutions of Company . . . . . . . . . . . . . . . . 9 4.3 Incumbency Certificate of the Company . . . . . . . . . 10 4.4 The Company's Organic Documents . . . . . . . . . . . . 10 4.5 Resolutions of the Guarantor . . . . . . . . . . . . . 10 4.6 Incumbency Certificate of the Guarantor . . . . . . . . 10 4.7 The Guarantor's Charter and By-Laws . . . . . . . . . . 10 4.8 Legal Opinions . . . . . . . . . . . . . . . . . . . . 10 4.9 Additional Information . . . . . . . . . . . . . . . . 10 ARTICLE V . . . . . . . . . . . . 10 REPRESENTATIONS AND WARRANTIES . . . . . . . . . . . . . . . . . 10 5.1 Representations and Warranties of the Company . . . . . 10 -i- ARTICLE VI . . . . . . . . . . . . 11 AFFIRMATIVE COVENANTS OF COMPANY . . . . . . . . . . . . . . . . 11 6.1 Affirmative Covenants . . . . . . . . . . . . . . . . . 11 ARTICLE VII . . . . . . . . . . . . 13 NEGATIVE COVENANTS OF COMPANY . . . . . . . . . . . . . . . . . . 13 7.1 Negative Covenants . . . . . . . . . . . . . . . . . . 13 ARTICLE VIII . . . . . . . . . . . . 14 EVENTS OF DEFAULT . . . . . . . . . . . . . . . . . . . . . . . . 14 8.1 Events of Default . . . . . . . . . . . . . . . . . . . 14 8.2 Remedies Upon Event of Default . . . . . . . . . . . . 15 ARTICLE IX . . . . . . . . . . . . 16 MISCELLANEOUS . . . . . . . . . . . . . . . . . . . . . . . . . . 16 9.1 Waiver . . . . . . . . . . . . . . . . . . . . . . . . 16 9.2 Notices . . . . . . . . . . . . . . . . . . . . . . . . 16 9.3 GOVERNING LAW . . . . . . . . . . . . . . . . . . . . . 17 9.4 Invalid Provisions . . . . . . . . . . . . . . . . . . 17 9.5 Entirety and Amendments . . . . . . . . . . . . . . . . 18 9.6 Headings . . . . . . . . . . . . . . . . . . . . . . . 18 9.7 Term of Agreement . . . . . . . . . . . . . . . . . . . 18 9.8 Indemnity . . . . . . . . . . . . . . . . . . . . . . . 18 9.9 Limitation of Liability . . . . . . . . . . . . . . . . 18 9.10 Obligations Absolute . . . . . . . . . . . . . . . . . 19 9.11 Survival of Representations and Warranties . . . . . . 19 9.12 Participations . . . . . . . . . . . . . . . . . . . . 19 9.13 Confidentiality . . . . . . . . . . . . . . . . . . . . 19 9.14 Right of Set-off . . . . . . . . . . . . . . . . . . . 19 9.15 Counterparts . . . . . . . . . . . . . . . . . . . . . 20 EXHIBIT A - Letter of Credit -ii- LETTER OF CREDIT AND REIMBURSEMENT AGREEMENT THIS LETTER OF CREDIT AND REIMBURSEMENT AGREEMENT is made and entered into as of this 8th day of March, 1994, by and between ENRON GAS & OIL TRINIDAD LIMITED, a corporation organized and existing under the laws of Trinidad & Tobago (the "COMPANY"), and CREDIT SUISSE, a Swiss banking corporation, acting through its New York Branch (the "BANK"). INTRODUCTION Pursuant to that certain Credit Agreement (the "Credit Agreement"), dated as of March 8, 1994 between the Company and Caribbean Regional Development Investment Trust ("CRDIT"), the Company has borrowed from CRDIT $31,000,000 (the "LOAN"). Pursuant to the terms of the Credit Agreement, the Company has agreed to provide an irrevocable letter of credit to support its performance and obligations under the Credit Agreement, the Loan, and the other documents executed in connection with the Credit Agreement and the Loan. The Company has requested that the Bank issue a letter of credit for such purpose, and the Bank has agreed to issue such a letter of credit, subject to the terms of this Agreement. Therefore, to effect the foregoing, the Company and the Bank hereby agree as follows: ARTICLE I DEFINITIONS 1.1 DEFINED TERMS. For the purposes of this Agreement, unless the context otherwise requires, the following terms shall have the respective meanings assigned to them in this ARTICLE I: "AGREEMENT" shall mean this Letter of Credit and Reimbursement Agreement as the same from time to time may be extended, amended, modified, supplemented, or waived. "BANK" shall have the meaning assigned to it in the preamble hereof. "BANKRUPTCY CODE" shall mean Title 11 of the United States Code entitled "Bankruptcy" as now or hereinafter in effect, or any successor thereto. "BASE RATE" shall mean, on any date, a rate per annum equal to the higher of (a) the base commercial lending rate announced from time to time by the Bank, or (b) the rate quoted by the Bank, at approximately 11:00 a.m., New York City time, to dealers in the New York Federal Funds Market for the overnight offering of dollars by the Bank for deposit, plus one-quarter of one percent (1/4%). The base lending rate is not the lowest rate of interest charged by the Bank in connection with extensions of credit. Each change in the Base Rate shall become effective without prior notice to the Company automatically as of the opening of business on the day of such change in the Base Rate. -1- "BENEFICIARY" shall mean, with respect to the Letter of Credit, CRDIT. "BUSINESS DAY" shall mean any day that is not (i) a Saturday, (ii) a Sunday, or (iii) another day on which (a) commercial banks in the City of New York, New York, Port of Spain, Trinidad, or San Juan, Puerto Rico are authorized or required by law or order to close or (b) the New York Stock Exchange is not open for trading. "CASH COLLATERAL ACCOUNT" shall have the meaning assigned to it in SECTION 3.2(a) hereof. "CASH COLLATERALIZED STATED AMOUNT" shall mean for each day of determination the amount of money (calculated in Dollars) in the Cash Collateral Account. "CLOSING DATE" shall mean the later of (a) the date of this Agreement, or (b) the date the Company has satisfied all of the conditions precedent set forth in ARTICLE IV hereof. "CODE" shall mean the Internal Revenue Code of 1986, as amended from time to time, or any successor Federal tax code, and any reference to any statutory provision of the Code shall be deemed to be a reference to any successor provision or provisions. "COMPANY" shall have the meaning assigned to it in the preamble hereof. "CONSOLIDATED" refers to the consolidation of the accounts of the Company and its Subsidiaries in accordance with GAAP. "CREDIT EXPIRATION DATE" shall mean the expiry date of the Letter of Credit. "DEBT" of any Person means, at any date, without duplication, (a) obligations for the repayment of money borrowed which are or should be shown on a balance sheet as debt in accordance with GAAP, (b) obligations as lessee under leases which, in accordance with GAAP, are capital leases, and (c) guaranties of payment or collection of any obligations described in clauses (a) and (b) of other Persons. "DOLLARS" and the sign "$" shall mean the lawful currency of the United States of America. "DRAWING" shall mean a demand for payment under the Letter of Credit in accordance with its terms. "EVENT OF DEFAULT" shall have the meaning assigned to it in SECTION 8.1 hereof. "GAAP" means generally accepted accounting principles, in effect from time to time, consistently applied. "GOVERNMENTAL AUTHORITY" shall mean each applicable national government and each political subdivision thereof, and all agencies, authorities, boards, bureaus, commissions, courts, -2- departments, officials, and officers of such governments now or hereafter having jurisdiction over any matter with respect of which such term is used. "GUARANTY" shall mean that certain Parent Guaranty of even date herewith executed by the Guarantor in favor of the Bank, pursuant to which the Guarantor guarantees the Company's Obligation under this Agreement. "GUARANTOR" shall mean Enron Oil & Gas Company, a Delaware corporation. "LETTER OF CREDIT FEE" shall have the meaning assigned to it in SECTION 3.1(b) hereof. "LETTER OF CREDIT" shall mean the letter of credit issued pursuant to this Agreement in the form of EXHIBIT A attached hereto. "NON-COLLATERALIZED STATED AMOUNT" shall mean for each day of determination the Stated Amount minus the amount of money (calculated in Dollars) in the Cash Collateral Account. "OBLIGATION" shall mean all present and future indebtedness, fees, commissions, obligations, covenants, and liabilities of the Company, and all renewals and extensions thereof, or any part thereof, arising pursuant to this Agreement or the Letter of Credit, and including without limitation any and all interest accruing thereon, and attorneys' fees incurred in the enforcement or collection thereof. "OTHER TAXES" shall have the meaning assigned to it in Section 3.1(f)(iii). "PERSON" shall mean an individual, sole proprietorship, partnership, joint venture, association, trust, estate, business trust, corporation, not-for-profit corporation, sovereign government or agency, instrumentality, or political subdivision thereof, or any similar entity or organization. "PRESCRIBED FORMS" shall mean such duly executed form(s) or statement(s), and in such number of copies, which may, from time to time, be prescribed by law and which, pursuant to applicable provisions of (a) an income tax treaty between the United States and the country of residence of the Bank, (b) the Code, or (c) any applicable rule or regulation under the Code, permit the Company to make payments hereunder for the account of the Bank free of deduction or withholding of income or similar taxes. "STATED AMOUNT" shall mean, for each day on which the Letter of Credit is in effect, the aggregate maximum amount which is available to be paid under the Letter of Credit. "SUBSIDIARY" means any corporation, partnership, joint venture or other entity of which more than 50% of the outstanding capital stock or other equity interests having ordinary voting power (irrespective of whether or not at the time capital stock or other equity interest of any other class or classes of such corporation, partnership, joint venture or other entity shall or might have voting power upon the occurrence of any contingency) is at the time directly or indirectly owned by the Company. -3- "TAXES" shall have the meaning assigned thereto in SECTION 3.1(f)(i) hereof. 1.2 OTHER DEFINITIONAL PROVISIONS. (a) All terms defined in this Agreement shall have the above-defined meanings when used in any certificate, report or other document made or delivered pursuant to this Agreement, unless the context therein shall otherwise require. (b) Defined terms used in the singular shall import the plural and VICE VERSA. (c) "Hereof," "herein," "hereunder," and similar terms when used in this Agreement shall refer to this Agreement as whole and not to any particular provisions of this Agreement. 1.3 ACCOUNTING TERMS. All accounting terms not specifically defined herein shall be construed in accordance with, and shall be based on, GAAP. ARTICLE II LETTER OF CREDIT FACILITY AND OPERATIONS 2.1 REQUEST FOR ISSUANCE OF LETTER OF CREDIT. The Company hereby applies to the Bank and requests the Bank to issue, execute, and deliver for its account on the CLOSING DATE, or on such date thereafter as the Company may request, the Letter of Credit. Subject to the terms and conditions of this Agreement, the Bank hereby agrees to issue the Letter of Credit. 2.2 NOTICE OF DRAWINGS. The Bank will provide the Company with telephonic notice (which notice shall be confirmed in writing) of each Drawing under the Letter of Credit at or before 1:00 p.m. (New York, New York time) on the Business Day on which the Bank will make the payment with respect to such Drawing. ARTICLE III REIMBURSEMENT AND PAYMENT OBLIGATIONS 3.1 REIMBURSEMENT AND PAYMENT OBLIGATIONS. In consideration of the issuance by the Bank of the Letter of Credit, the Company hereby agrees to pay to the Bank the amounts set forth in this ARTICLE III on the dates and in the manner provided herein: (a) REIMBURSEMENT OF DRAWINGS UNDER THE LETTER OF CREDIT. An amount equal to the face amount of each Drawing, whether an Interest Drawing or a Principal Drawing (as such capitalized terms are defined in the Letter of Credit), which amount is due and payable to the Bank on the same Business Day on which the Bank duly honors any such Drawing, unless and to the extent the Bank (1) has been reimbursed for such amount from the Cash Collateral -4- Account pursuant to SECTION 3.2(b) or (2) has used funds in the Cash Collateral Account to pay the installment of interest or principal due under the Loan pursuant to SECTION 3.2(b). (b) FEES. The Company shall pay to the Bank a letter of credit fee (the "LETTER OF CREDIT FEE") equal to the sum of (x) 0.5% per annum on the Non-Collateralized Stated Amount of the Letter of Credit plus (y) 0.125% per annum on the Cash Collateralized Stated Amount of the Letter of Credit, payable quarterly in arrears from the date of issuance of the Letter of Credit, commencing on April 1, 1994, and continuing on the first Business Day of each July, October, January, and April thereafter through and including the Credit Expiration Date; and any accrued but unpaid fee as of the Credit Expiration Date shall be due and payable on the Credit Expiration Date. The Letter of Credit Fee shall be calculated on the basis of the actual days elapsed in a year consisting of 365 or 366 days, as the case may be. (c) INTEREST. Interest on the Obligation from time to time unpaid at a rate per annum equal to the sum of (x) the Base Rate MULTIPLIED by (y) 125% (but in no event to exceed the maximum rate of interest permitted by law), is payable on demand. Any such interest payable hereunder shall be calculated on the basis of actual days elapsed in a year consisting of 365 or 366 days, as applicable. (d) ADDITIONAL COSTS. (i) Amounts sufficient to fully compensate the Bank for any additional costs resulting from the introduction of or change in any law, rule, regulation, guideline or request or in the interpretation thereof by any Governmental Authority, central bank or comparable agency (whether or not having the force of law) charged with the administration of such law, rule, regulation or guideline which directly or indirectly (A) imposes or modifies or deems applicable any reserve, special deposit or similar requirement against letters of credit issued by the Bank, (B) increases the amount of capital required or expected to be maintained or funded against letters of credit issued by the Bank or any corporation controlling the Bank, and (C) imposes on the Bank some condition regarding this Agreement, and the result of any event referred to in (A), (B) or (C) above shall be to increase the cost to the Bank of issuing or maintaining the Letter of Credit, payable on demand. Promptly after the Bank becomes aware of any such introduction, change or proposed compliance, the Bank shall notify the Company thereof, PROVIDED that the failure to provide such notice shall not affect the Bank's rights under this SECTION 3.1(d). A certificate in reasonable detail as to such increased cost, which states the basis of calculation thereof, submitted by the Bank to the Company shall be conclusive, absent manifest error, as to the amount thereof. Such certificate shall certify that such costs are generally being charged by the Bank to other similarly situated companies in connection with the issuance and maintenance of, or agreements to issue, similar letters of credit. Such increase in cost shall be based upon a reasonable allocation of Bank's aggregate cost related to the Letter of Credit. Notwithstanding the foregoing, the Company shall not be obligated to reimburse the Bank pursuant to any provision of this SECTION 3.1(d) for any additional costs under (A), (B), or (C) above, incurred or accruing more than 90 days prior to the date on which the Bank gave the written notice specified above. -5- (ii) Amounts sufficient to compensate the Bank for any additional costs resulting from a demand for payment under the Letter of Credit on a day other than a Business Day. Any amounts payable pursuant to this SECTION 3.1(d)(ii) shall be for a period not to exceed the number of days the Bank would have had to pay such demand if demands for payment and amounts paid under the Letter of Credit were to be made only on Business Days. A certificate in reasonable detail as to any such cost, which states the basis of calculation thereof, submitted by the Bank to the Company shall be conclusive, absent manifest error, as to the amount thereof. (e) EXPENSES. Costs and actual reasonable expenses of the Bank (including, without limitation, the reasonable attorneys' fees of the Bank's legal counsel) incurred by the Bank in connection with (a) the presentation and enforcement of all of the Bank's rights under this Agreement and the Letter of Credit, and (b) the negotiation, preparation, execution, delivery and participation of this Agreement, the Letter of Credit and any other documents related thereto, and any and all amendments, modifications and supplements thereof or thereto. (f) TAXES. (i) Amounts sufficient such that any and all payments by the Company hereunder, and the Guarantor under the Guaranty, shall be made, in accordance with SECTION 3.3 hereof, free and clear of and without deduction for any and all present or future taxes, levies, imposts, deductions, charges or withholdings, and all liabilities with respect thereto, EXCLUDING (A) taxes imposed on the Bank's income, and franchise taxes imposed on it, by the jurisdiction under the laws of which the Bank is organized or any political subdivision thereof and, taxes imposed on its income, and franchise taxes imposed on it, by the jurisdiction of the Bank's lending office or any political subdivision thereof and (B) any taxes imposed by the United States of America by means of withholding at the source if and to the extent that such taxes shall be in effect and shall be applicable, on the date hereof, to payments to be made to the Bank (all such non-excluded taxes, levies, imposts, deductions, charges, withholdings and liabilities being hereinafter referred to as "TAXES"). If the Company (or the Guarantor) shall be required by law to deduct any Taxes from or in respect of any sum payable hereunder (or under the Guaranty) to the Bank, (1) the sum payable shall be increased as may be necessary so that after making all required deductions (including deductions applicable to additional sums payable under this SECTION 3.1(f)) the Bank receives an amount equal to the sum it would have received had no such deductions been made, (2) the Company (or the Guarantor) shall make such deductions, and (3) the Company (or the Guarantor) shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law. (ii) Notwithstanding anything to the contrary contained in this Agreement (or under the Guaranty), the Company (or the Guarantor) shall be entitled, to the extent it is required to do so by law, to deduct or withhold income or other similar taxes imposed by the United States of America from interest, fees or other amounts payable hereunder for the account of the Bank (without the payment of increased amounts to the Bank pursuant to clause (i) above), unless the Bank (A) is a domestic corporation -6- (as such term is defined in Section 7701 of the Code) for Federal income tax purposes or (B) has the Prescribed Forms on file with the Company (or the Guarantor) for the applicable year to the extent deduction or withholding of such taxes is not required as a result of the filing of such Prescribed Forms, provided that if the Company (or the Guarantor) shall so deduct or withhold any such taxes, it shall provide a statement to the Bank, setting forth the amount of such taxes so deducted or withheld, the applicable rate and any other information or documentation which the Bank may reasonably request for assisting the Bank to obtain any allowable credits or deductions for the taxes so deducted or withheld in the jurisdiction or jurisdictions in which the Bank is subject to tax. (iii) In addition, the Company agrees to pay any present or future stamp or documentary taxes or any other excise or property taxes, charges or similar levies imposed by any Governmental Authority which arise from any payment made hereunder or from the execution, delivery or registration of, otherwise with respect to, this Agreement (hereinafter referred to as "OTHER TAXES"). (iv) The Company will, to the fullest extent permitted by law, indemnify the Bank for the full amount of Taxes or Other Taxes (including, without limitation, any Taxes or Other Taxes imposed by any Governmental Authority on amounts payable under this SECTION 3.1(f)) paid by the Bank and any liability (including penalties, interest and expenses) arising therefrom or with respect thereto except as a result of the negligence or willful misconduct of the Bank, whether or not such Taxes or Other Taxes were correctly or legally asserted. This indemnification shall be made within 30 days from the date the Bank makes written demand therefor. The Bank shall not be indemnified pursuant to this SECTION 3.1(f)(iv) for Taxes or Other Taxes incurred or accrued more than 90 days prior to the date that the Bank makes written demand to the Company therefor. (v) Within 30 days after the date of any payment of Taxes by or at the direction of the Company, the Company will furnish to the Bank, at its address referred to in SECTION 9.2 hereof, the original or a certified copy of a receipt evidencing payment thereof. Should the Bank ever receive any refund, credit or deduction from any taxing authority to which the Bank would not be entitled but for the payment by the Company of Taxes as required by this SECTION 3.1(f) (it being understood that the decision as to whether or not to claim, and if claimed, as to the amount of any such refund, credit or deduction shall be made by the Bank in its sole discretion), the Bank thereupon shall repay to the Company an amount with respect to such refund, credit or deduction equal to any net reduction in taxes actually obtained by the Bank and determined by the Bank to be attributable to such refund credit or deduction. (vi) The Bank shall use its best efforts (consistent with its internal policies and legal and regulatory restrictions) to select a jurisdiction for its lending office or change the jurisdiction for its lending office, as the case may be, so as to avoid the imposition of any Taxes or Other Taxes or to eliminate the amount of any such additional amounts which may thereafter accrue; PROVIDED that no such selection or change of the -7- jurisdiction for its lending office shall be made if, in the reasonable judgment of the Bank, such selection or change would be disadvantageous to the Bank. (vii) Without prejudice to the survival of any other agreement of the Company hereunder, the agreements and obligations of the Company contained in this SECTION 3.1(f) shall survive the payment in full of the Obligation for a period of five years thereafter. 3.2 CASH COLLATERAL ACCOUNT. (a) ESTABLISHMENT OF ACCOUNT. Of even date herewith, the Company has established a non-interest bearing deposit account No. 34911901 (the "CASH COLLATERAL ACCOUNT") with Credit Suisse, New York Branch, entitled "Enron Gas & Oil Trinidad Limited Credit Suisse Reimbursement Account", and such Cash Collateral Account shall be maintained at all times thereafter, until the expiration or earlier termination of the Letter of Credit and the reimbursement to the Bank, in full, of all Drawings made under the Letter of Credit. From time to time the Company may deposit funds in any amount into the Cash Collateral Account. At least one (1) Business Day prior to the date that each installment of interest or principal becomes due under the Loan, the Company shall deposit funds, in an amount sufficient to pay such installment, into the Cash Collateral Account. (b) CONTROL OF, AND PAYMENTS FROM ACCOUNT. The Cash Collateral Account and all amounts deposited therein shall be subject to the exclusive dominion and control of the Bank. The Bank may apply the funds in the Cash Collateral Account to any reimbursement and payment obligation contained in SECTION 3.1(a) of this Agreement. All interest received on any investment of the funds in the Cash Collateral Account shall be income to the Company, shall be credited to the Cash Collateral Account, and shall be a part of, and disbursed from, the Cash Collateral Account in accordance with this Agreement. Notwithstanding anything contained herein to the contrary, upon the occurrence of an Event of Default, the Bank may apply the funds in the Cash Collateral Account to the payment of any Obligation. (c) GRANT OF SECURITY INTEREST. To secure the Obligation, the Company hereby transfers, assigns, and grants a security interest to the Bank in the Cash Collateral Account and all amounts deposited therein, together with all investments and proceeds thereof, from the date of the establishment of the Cash Collateral Account until the termination thereof pursuant to the terms hereof. 3.3 ILLEGALITY. Notwithstanding any other provision in this Agreement, if the Bank determines that any applicable law, rule, or regulation or any change therein, or any change in the interpretation or administration thereof by any Governmental Authority, central bank, or comparable agency charged with the interpretation or administration thereof, or compliance by the Bank (or by its lending office) with any request or directive (whether or not having the force of law) of any such authority, central bank, or comparable agency shall make it unlawful or impossible for the Bank (or its respective lending office) to maintain the Letter of Credit, then -8- upon notice to the Company by the Bank, the same shall constitute an "Event of Default" hereunder. 3.4 METHOD OF PAYMENT. Except with respect to the Bank's satisfaction of certain reimbursement obligations of the Company from the Cash Collateral Account pursuant to SECTION 3.2(b), all payments by the Company to the Bank hereunder shall be made by 2:00 p.m. New York, New York time, free and clear of set-off or counterclaim in lawful currency of the United States and in immediately available funds through the New York Clearing House Interbank Payments System or through the New York Federal Reserve Bank at the Bank's office at 12 E. 49th Street, New York, New York 10017. If any such payment becomes due and payable on a day other than a Business Day, the same shall be payable on the next succeeding Business Day, but in any event not later than the last Business Day prior to the Credit Expiration Date. ARTICLE IV CONDITIONS PRECEDENT TO ISSUANCE OF LETTER OF CREDIT The effectiveness of this Agreement and the obligation of the Bank to issue the Letter of Credit shall be subject to the conditions precedent that the Bank shall have received on the Closing Date, unless otherwise expressly stated, all of the following (in such quantities as may be requested by the Bank), each dated or effective as of the date hereof (unless otherwise stated below) in form and substance satisfactory to Bank: 4.1 GUARANTY. The Guaranty, duly executed by the Guarantor. 4.2 RESOLUTIONS OF COMPANY. Resolutions of the Board of Directors of the Company approving the execution, delivery, and performance of this Agreement and the transactions contemplated herein, duly adopted by the Board of Directors of the Company and accompanied by a certificate of the Secretary or an Assistant Secretary of the Company stating that such resolutions are true and correct, have not been altered or repealed, and are in full force and effect. 4.3 INCUMBENCY CERTIFICATE OF THE COMPANY. A certificate executed by a duly-authorized officer of the Company which shall certify the names of the officers of the Company authorized to execute this Agreement and the other documents or certificates to be delivered pursuant to this Agreement by the Company, together with the true signatures of each such officer. 4.4 THE COMPANY'S ORGANIC DOCUMENTS. A copy of the memorandum and articles of association of the Company, and all amendments thereto, certified by the Secretary or an Assistant Secretary of the Company, as being true, correct, and complete as of the date of such certification. -9- 4.5 RESOLUTIONS OF THE GUARANTOR. Resolutions of the Board of Directors of the Guarantor approving the execution, delivery, and performance of the Guaranty, duly adopted by the Board of Directors of the Guarantor and accompanied by a certificate of the Secretary or an Assistant Secretary of the Guarantor stating that such Resolutions are true and correct, have not been altered or repealed, and are in full force and effect. 4.6 INCUMBENCY CERTIFICATE OF THE GUARANTOR. A certificate executed by a duly-authorized officer of the Guarantor which shall certify the names of the officers of the Guarantor authorized to execute the Guaranty and the other documents or certificates to be delivered pursuant to the Guaranty by the Guarantor, together with true signatures of each such officer. 4.7 THE GUARANTOR'S CHARTER AND BY-LAWS. A copy of the restated certificate of incorporation of the Guarantor, and all amendments thereto, and a copy of the by-laws of the Guarantor, and all amendments thereto, both certified by the Secretary or an Assistant Secretary of the Guarantor, as being true, correct, and complete as of the date of such certification. 4.8 LEGAL OPINIONS. Opinions of counsel to the Company and to the Guarantor, which opinions shall be from counsel satisfactory to the Bank, and in form and substance satisfactory to the Bank. 4.9 ADDITIONAL INFORMATION. Such other information and documents as may reasonably be required by the Bank and its counsel. ARTICLE V REPRESENTATIONS AND WARRANTIES 5.1 REPRESENTATIONS AND WARRANTIES OF THE COMPANY. To induce the Bank to issue the Letter of Credit, the Company represents and warrants to the Bank that: (a) The Company is a corporation duly incorporated, validly existing and in good standing under the laws of its jurisdiction of incorporation. The Company has all corporate powers and all material governmental licenses, authorizations, consents and approvals required to carry on its business as now conducted. (b) The execution, delivery and performance by the Company of this Agreement are within the Company's corporate powers, have been duly authorized by all necessary corporate action of the Company, require, in respect of the Company, no action by or in respect of, or filing with, any governmental body, agency or official and do not contravene, or constitute a default under, any provision of law or regulation applicable to the Company or the restated certificate of incorporation or by-laws of the Company or any judgment, injunction, order, decree or material ("material" for the purposes of this representation meaning creating a liability of $5,000,000 or more) agreement binding upon the -10- Company or result in the creation or imposition of any lien, security interest or other charge or encumbrance on any asset of the Company. (c) This Agreement, has been duly executed and delivered by the Company and is the legal, valid, and binding obligation of the Company enforceable against the Company in accordance with its terms, except as the enforceability thereof may be limited by the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting creditors' rights generally and by general principles of equity. (d) Since December 31, 1993, there has been no material adverse change in the financial position or results of operations of the Company. (e) Except as previously disclosed in writing by the Company to the Bank prior to the date hereof, there is no action, suit or proceeding pending against the Company, or to the knowledge of the Company threatened against the Company, before any court or arbitrator or any governmental body, agency or official in which there is a reasonable possibility of an adverse decision which could materially adversely affect the financial position or results of operations of the Company or which in any manner draws into question the validity of this Agreement. ARTICLE VI AFFIRMATIVE COVENANTS OF COMPANY 6.1 AFFIRMATIVE COVENANTS. The Company covenants and agrees that so long as the Letter of Credit shall be outstanding, and until payment in full of all Drawings made under the Letter of Credit, the Company will (unless the Bank shall otherwise consent in writing): (a) COMPLIANCE WITH LAWS, ETC. Comply in all material respects, with all applicable laws, rules, regulations and orders to the extent noncompliance therewith would have a material adverse effect on the Company, such compliance to include, without limitation, the paying before the same become delinquent of all taxes, assessments and governmental charges imposed upon it or upon its property except to the extent contested in good faith. (b) PRESERVATION OF CORPORATE EXISTENCE, ETC. Preserve and maintain its corporate existence, rights (charter and statutory), and franchises; PROVIDED, HOWEVER, that the Company shall not be required to preserve any right or franchise if the Company shall determine that the preservation thereof is no longer desirable in the conduct of the business of the Company, and that the loss thereof is not disadvantageous in any material respect to the Banks. (c) REPORTING REQUIREMENTS. Furnish to the Bank the following: -11- (i) immediately following the occurrence of each Event of Default, a statement of a director knowledgeable about the Company's financial affairs setting forth details of such Event of Default and the action which it proposes to take with respect thereto; (ii) as soon as available, and in any event within 90 days after the end of each fiscal year, a statement of a director knowledgeable about the Company's financial affairs stating that no Event of Default under Article VIII of this Agreement has occurred and is continuing or, if an Event of Default has occurred and is continuing, a statement as to the nature thereof and the action which it proposes to take with respect thereto; (iii) as soon as available, and in any event within sixty (60) days after the close of each of the first three (3) quarters of each fiscal year of the Company, the unaudited balance sheet of the Company as at the end of such quarter and the related statements of income and cash flows of the Company for such quarter and for the elapsed portion of the fiscal year ended with the last day of such quarter, in each case setting forth comparative figures for the related periods in the prior fiscal year, prepared in accordance with GAAP, all of which shall be certified by a director knowledgeable about the Company's financial affairs, subject to normal year-end audit adjustments; (iv) as soon as available, and in any event within ninety (90) days after the close of each fiscal year of the Company, a copy of the audited financial statements for such year for the Company, including therein a balance sheet of the Company as at the end of such fiscal year and the related statements of income and cash flows of the Company for such fiscal year prepared in accordance with GAAP; and (v) such other information with respect to the Company's business, properties, or its condition or operations, financial or otherwise, as the Bank may from time to time reasonably request. ARTICLE VII NEGATIVE COVENANTS OF COMPANY 7.1 NEGATIVE COVENANTS. The Company covenants and agrees that so long as the Letter of Credit shall be outstanding, and until payment in full of all Drawings made under the Letter of Credit, the Company will not (unless the Bank shall otherwise consent in writing): (a) CORPORATE REORGANIZATIONS. Wind up, liquidate, dissolve itself, reorganize, merge or consolidate with or into, or convey, sell, assign, transfer, lease, or otherwise dispose of (whether in one transaction or a series of transactions) all or substantially all of its assets (whether now owned or hereafter acquired) to, any Person, except if the corporation into which the Company is merged or a corporation formed by such consolidation or the Person acquiring all or substantially all of the Company's assets: -12- (i) shall be a corporation organized and existing under the laws of a "Qualified Caribbean Basin Country" (as defined in Section 936(d)(4)(B) of the Code); (ii) shall assume, by an instrument in form and substance satisfactory to the Bank, the due and punctual payment of the Obligation, as fully as if such successor had been the Company; and (iii) immediately after such transaction no event shall occur and be continuing which constitutes an Event of Default. (b) NEGATIVE PLEDGE. Create, incur, assume, or suffer to exist any mortgage, deed of trust, pledge, lien, security interest, hypothecation, assignment, deposit arrangement, charge, or encumbrance (including, without limitation, any conditional sale, or other retention agreement, or finance lease) of any nature, upon or with respect to any of its assets or properties, now owned or hereafter acquired, or sign or file under the Uniform Commercial Code of any jurisdiction, a financing statement which names the Company as a debtor, or sign any security agreement authorizing any secured party thereunder to file such financing statement, except: (i) mortgages, deeds of trust, pledges, liens, security interests, assignments, deposit arrangements, or other preferential arrangements, charges, or encumbrances in favor of the Bank; (ii) liens for taxes or assessments or other governmental charges or levies if not yet due and payable or, if due and payable, if they are being contested in good faith by appropriate proceedings and for which appropriate reserves are maintained; (iii) pledges in favor of Guarantor; (iv) undetermined or inchoate liens or charges incidental to the construction, operation, maintenance, development of oil and gas fields off the coast of Trinidad and Tobago by the Company; (v) obligations or duties of the Company to any municipality or Governmental Authority with respect to any franchise, grant, license, permit, or similar arrangement; (vi) judgment liens the aggregate amount of which does not exceed $5,000,000, or the aggregate amount of which is greater, if such greater amount is stayed by appeal, or which has been appealed and secured, if necessary, by the filing of an appeal bond; (vii)the pledge of hydrocarbons produced or recovered from any property, an interest in which is owned or leased by the Company; -13- (viii)the pledge of current assets to secure current liabilities, if in the ordinary course of business; and (ix) mechanics' and/or materialmen's liens. ARTICLE VIII EVENTS OF DEFAULT 8.1 EVENTS OF DEFAULT. An "Event of Default" shall exist if any one or more of the following events (herein collectively called "EVENTS OF DEFAULT") shall occur and be continuing: (a) the Company shall fail to deposit funds into the Cash Collateral Account as described in Section 3.2(a) or otherwise to reimburse the Bank for the amount of any Drawing (and such failure continues for one (1) Business Day), to pay interest on the Obligation, or to pay any fees (including without limitation the Letter of Credit Fee) when the same becomes due and payable hereunder; or (b) any representation or warranty made by (i) the Company (or any of its officers) under or in connection with this Agreement or (ii) the Guarantor under or in connection with the Guaranty, shall prove to have been incorrect in any material respect when made or deemed made and such materiality is continuing; or (c) the Company shall fail to perform or observe any term, covenant or agreement contained in SECTIONS 6.1 or 7.1 or shall fail to perform or observe any other term, covenant or agreement contained in this Agreement on its part to be performed or observed if, in the case of such other term, covenant or agreement, such failure shall remain unremedied for 30 days after written notice thereof shall have been given to the Company by the Bank; or (d) the Company shall fail to pay any principal of or premium or interest on any Debt (other than the Loan) which is outstanding in the principal amount of at least $5,000,000 in the aggregate, of the Company, when the same becomes due and payable (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and such failure shall continue after the applicable grace period, if any, specified in the agreement or instrument relating to such Debt; or any other event shall occur or condition shall exist under any agreement or instrument relating to any such Debt and shall continue after the applicable grace period, if any, specified in such agreement or instrument, if the effect of such event or condition is to accelerate the maturity of such Debt; or any such Debt shall be declared to be due and payable, or required to be prepaid (other than by a regularly scheduled required prepayment or as a result of the giving of notice of a voluntary prepayment), prior to the stated maturity thereof; or (e) the Company shall generally not pay its debts as such debts become due, or shall admit in writing its inability to pay its debts generally, or shall make a general assignment for the benefit of creditors; or any proceeding shall be instituted by or against the -14- Company seeking to adjudicate it as bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief or composition of it or its debts under any law relating to bankruptcy, insolvency or reorganization or relief of debtors, or seeking the entry of an order for relief or the appointment of a receiver, trustee or other similar official for it or for any substantial part of its property and, in the case of any such proceeding instituted against it (but not instituted by it), shall remain undismissed or unstayed for a period of 60 days; or the Company shall take any corporate action to authorize any of the actions set forth above in this subsection (e); or (f) one or more judgments, decrees, orders for the payment of money in excess of $5,000,000 in the aggregate shall be rendered against the Company and such judgments, decrees, or orders shall continue unsatisfied and in effect for a period of thirty (30) consecutive days without being vacated, discharged, satisfied, stayed or bonded pending appeal; (g) the Company shall cease to be wholly-owned by Guarantor either directly or indirectly; or (h) the occurrence of any of the events described in SECTION 3.3, and the delivery of notice of such occurrence to the Company. 8.2 REMEDIES UPON EVENT OF DEFAULT. If an Event of Default shall occur and be continuing, then (a) the Company shall pay to the Bank immediately the unpaid amount of any of the remainder of the Obligation then due and owing to the Bank without presentment, demand, protest or any notice of any kind, all of which are hereby expressly waived by the Company and (b) the Bank may, at its election, by notice in writing given to the Beneficiary, declare the Letter of Credit to be terminated, effective seven (7) days after the date of the Beneficiary's receipt of such notice of termination. ARTICLE IX MISCELLANEOUS 9.1 WAIVER. No failure to exercise, and no delay in exercising, on the part of Bank, any right hereunder shall operate as a waiver thereof, nor shall any single or partial exercise thereof preclude any other further exercise thereof or the exercise of any other right. The rights of Bank hereunder shall be in addition to all other rights provided by law. No modification or waiver of any provision of this Agreement, nor consent to departure therefrom, shall be effective unless in writing and no such consent or waiver shall extend beyond the particular case and purpose involved. No notice or demand given in any case shall constitute a waiver of the right to take other action in the same, similar or other instances without such notice or demand. 9.2 NOTICES. Except where otherwise provided herein, all instructions, notices and other communications to be given to any party hereto shall be in writing and shall be personally delivered or sent by first-class mail, or by telecopier, and shall be deemed to be given for purposes of this Agreement on the day when delivered or sent (except if sent by certified mail -15- they shall be deemed to be given on the 5th Business Day after the day on which mailed) to the intended party at its address or telecopier number specified below (or as such party may specify to the other parties in writing). Any requirement that notice be given to any person under this Agreement shall be deemed to require notice to every person listed below. The addresses of the Bank and the Company for notices are: If to Bank: Credit Suisse 12 E. 49th Street New York, New York 10017 Attention: Hazel Leslie Telephone: (212) 612-8055 Telecopier: (212) 612-8368 with a copy to:Credit Suisse Houston Representative Office 1100 Louisiana, Suite 4750 Houston, Texas 77002 Attention: Donald W. Herrick, Jr. Vice President Telephone: (713) 751-0300 Telecopier: (713) 751-0702 If to Company: Enron Gas & Oil Trinidad Limited Second Floor, The Mutual Center 16 Queens Park West Port of Spain Republic of Trinidad and Tobago British West Indies Attention: General Manager Telephone: (809) 622-8653 Telecopier: (809) 628-4218 with a copy to:Enron Gas & Oil Trinidad Limited 1400 Smith Street Houston, Texas 77002 Attention: Walter S. Wilson, Director Telephone: (713) 853-5012 Telecopier: (713) 646-8062 Any party may change its address for purposes of this Agreement by giving notice of such change to the other parties pursuant to this SECTION 9.2. 9.3 GOVERNING LAW. THIS AGREEMENT AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE GOVERNED BY AND -16- CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK AND THE APPLICABLE FEDERAL LAWS OF THE UNITED STATES OF AMERICA. 9.4 INVALID PROVISIONS. If any provision of this Agreement is held to be illegal, invalid, or unenforceable under present or future laws effective during the term of this Agreement, such provision shall be fully severable and this Agreement shall be construed and enforced as if such illegal, invalid or unenforceable provision had never comprised a part of this Agreement, and the remaining provisions of this Agreement shall remain in full force and effect and shall not be affected by the illegal, invalid or unenforceable provision or by its severance from this Agreement, unless such continued effectiveness of this Agreement, as modified, would be contrary to the basic understandings and intentions of the parties as expressed herein. 9.5 ENTIRETY AND AMENDMENTS. This Agreement and the documents, instruments and agreements referred to herein embody the entire agreement between the parties and supersedes all prior agreements and understandings, if any, relating to the subject matter hereof, and this Agreement may be amended only by an instrument in writing executed by an authorized officer of Company and the Bank. The Company hereby agrees that the terms and provisions of this Agreement shall be applicable to any amendment, modification or supplement hereinafter made to the Letter of Credit with the written consent of the Company and the Bank, with the same force and effect as if such amendment, modification or supplement had been fully described herein. 9.6 HEADINGS. Section headings are for convenience of reference only and shall in no way affect the interpretation of this Agreement. 9.7 TERM OF AGREEMENT. This Agreement shall remain in full force and effect until the later of the payment in full of the Obligation and the expiration of the Letter of Credit (or return and cancellation of the Letter of Credit). 9.8 INDEMNITY. To the fullest extent permitted by law, the Company hereby agrees to indemnify the Bank and hold the Bank harmless from and against any and all claims, damages, losses, liabilities, costs or expenses which may arise or be asserted against the Bank in connection with the Letter of Credit, provided, however, that such indemnity shall not apply to any such claims, damages, losses, liabilities, costs or expenses caused by, arising from or existing solely by reason of (a) any wrongful breach by the Bank of any of its obligations under this Agreement or the Letter of Credit or (b) the gross negligence or willful misconduct of the Bank. In the event the Bank is restrained or enjoined from payment to the Beneficiary under the Letter of Credit pursuant to any judicial, governmental or quasi-governmental proceeding, the Company agrees to (i) reimburse the Bank for all costs and attorneys' fees reasonably incurred by the Bank in connection with (A) such proceeding and (B) any actions or claims of the Beneficiary against the Bank resulting from or notwithstanding such restraint or injunction, and (ii) extend the period during which Company's Obligation shall remain in full force and effect for as long a period of time as the expiration date of the Letter of Credit is extended by virtue of such restraint or injunction. -17- 9.9 LIMITATION OF LIABILITY. The Bank shall not be liable for (a) any acts or omission of the Beneficiary; (b) the form, accuracy, authority of persons signing, or legal effect of any documents required under the Letter of Credit provided such documents appear on their face to be in order; (c) the failure of any draft to bear any reference or adequate reference to the Letter of Credit; (d) errors, omissions, interruptions or delays in transmission or delivery of any messages, however sent; and (e) without limiting the foregoing, any action taken or omitted by the Bank in good faith in connection with the validity, sufficiency, or genuineness of any document or instrument presented to the Bank in connection with the Letter of Credit provided such document or instrument appears on its face to be in order, even if such document or instrument should in fact prove to be in any or all respects invalid, fraudulent, or forged. 9.10 OBLIGATIONS ABSOLUTE. The obligations of the Company under this Agreement shall be absolute, unconditional (except insofar as the duty to reimburse future Drawings represents contingent obligations) and irrevocable and shall be paid and performed strictly in accordance with the terms hereof. To the maximum extent permitted by applicable law the liability of the Company under this Agreement shall not be affected by the occurrence of any event or circumstance including, without limitation, any of the following: (a) any lack of validity or enforceability of all or any part of the Guaranty; (b) the amendment or waiver of all or any of the terms of any or all of the Guaranty; or (c) the existence of any claim, set-off, defense or other right which the Company may have at any time against the Bank, the Beneficiary or any transferee of the Letter of Credit, or any other person or entity, whether in connection with this Agreement, the Letter of Credit, the transactions contemplated herein or therein, or any unrelated transaction or matter. 9.11 SURVIVAL OF REPRESENTATIONS AND WARRANTIES. All of the representations and warranties by the Company herein shall survive delivery of this Agreement and the issuance of the Letter of Credit, and any investigation at any time made by or on behalf of the Bank shall not diminish the Bank's right to rely thereon. 9.12 PARTICIPATIONS. The Bank may sell or grant participations in any of its rights or duties hereunder or under the Letter of Credit. 9.13 CONFIDENTIALITY. The Bank agrees that it will use reasonable efforts not to disclose without the prior consent of the Company (other than to its employees, auditors or counsel) any information with respect to the Company which is furnished pursuant to this Agreement and which is designated by the Company to the Bank in writing as confidential, provided that the Bank may disclose any such information, (a) as has become generally available to the public, (b) as may be required or appropriate in any report, statement or testimony submitted to any regulatory body having or claiming to have jurisdiction over the Bank (whether in the United States or elsewhere), (c) as may be required or appropriate in response to any summons or subpoena or in connection with any litigation, and (d) in order to comply with any law, order, regulation or ruling applicable to the Bank, and (e) to a prospective participant in connection with any contemplated transfer of any participation interest in the Agreement, and the obligations of the Company under this Agreement, provided, that such prospective participant executes an agreement with the Bank containing provisions substantially identical to those contained in this SECTION 9.13. -18- 9.14 RIGHT OF SET-OFF. Upon the occurrence of, and during the continuance of, an Event of Default, the Bank is hereby authorized at any time and from time to time, to the fullest extent permitted by law, to set off and apply against the Obligation, any and all balances in every deposit account of the Company with the Bank or any affiliate, office, or agency of the Bank now or at any time hereafter existing, any and all other rights or claims of the Company against the Bank and any affiliate, office, or agency of the Bank and any and all money, instruments, securities, documents, chattel paper, or other property rights of the Company which may now or at anytime hereafter be in possession or custody or under control of the Bank or any affiliate, office, or agency of the Bank, and the proceeds, products, and accessions of and to any thereof. The Bank agrees to notify the Company after any such set-off and application made by the Bank, PROVIDED that the failure to give such notice shall not affect the validity of such set-off and application. The rights of the Bank under this Section 9.14 are in addition to other rights and remedies (including, without limitation other rights of set-off) which the Bank may have. 9.15 COUNTERPARTS. This Agreement may be executed in any number of counterparts, each of which when so executed shall be deemed to be an original and all of which taken together shall constitute one and the same agreement. EXECUTED as of the date first set forth above. COMPANY: ENRON GAS & OIL TRINIDAD LIMITED By: Name: W. C. Wilson Title: Director BANK: CREDIT SUISSE, a Swiss banking corporation, acting through its New York Branch By: Name: Geoffrey M. Craig Title: Member of Senior Management By: Name: William P. Murray Title: Member of Senior Management -19- EXHIBIT A IRREVOCABLE DIRECT-PAY LETTER OF CREDIT March 8, 1994 Letter of Credit No. ______________ Caribbean Regional Development Investment Trust c/o Banco Central Hispano-Puerto Rico, as Trustee 221 Ponce de Leon Avenue, Suite 1115 San Juan, Puerto Rico 00919 Attention: Corporate Trust Officer Dear Sirs: We hereby establish, at the request and for the account of Enron Gas & Oil Trinidad Limited (the "Account Party"), in your favor, our Irrevocable Direct-Pay Letter of Credit No. __________________________, in the amount of $31,861,111.11 (such amount, as reduced and reinstated from time to time in accordance with the provisions hereof, being the "Stated Amount"), of which (i) an amount not exceeding $31,000,000 (such amount, as reduced from time to time in accordance with the provisions hereof, being the "Principal Component") may be drawn upon with respect to the payment of principal of that certain loan made pursuant to that certain Credit Agreement, dated as of March 8, 1994, between you and the Account Party (the "Loan") and (ii) an amount not exceeding $861,111.11 (100 days accrued interest on the then effective Principal Component at the rate of 10% per annum) (such amount, as reduced and reinstated from time to time in accordance with the provisions hereof, being the "Interest Component") may be drawn upon with respect to the payment of interest accrued on the Loan. We hereby irrevocably authorize you to draw on us, in accordance with the terms and conditions hereof, (i) in one or more drawings by one or more of your drafts drawn on us (each such drawing being an "Interest Drawing") and accompanied by your written and completed certificate in substantially the form of ANNEX I attached hereto, an amount not exceeding $861,111.11 (as such amount is reduced and reinstated from time to time in accordance with the provisions hereof), with respect to payment when due of interest accrued on the Loan; (ii) in one or more drawings by one or more of your drafts drawn on us (each such drawing being a "Principal Drawing") and accompanied by your written and completed certificate in substantially the form of ANNEX II attached hereto, an amount not exceeding $31,000,000 (as such amount is reduced from time to time in accordance with the provisions hereof), with respect to the payment when due of the principal of the Loan; and (iii) in a single drawing by your draft drawn on us (such drawing being the "Final Drawing") and accompanied by your written and completed certificate in substantially the form of ANNEX III attached hereto, an amount not exceeding $31,861,111.11 (as such amount is reduced and reinstated from time to time in accordance with the provisions hereof), with respect to the payment, upon the acceleration of the principal of and interest accrued on the Loan. Funds under this Letter of Credit are available to you against your sight draft(s) drawn on us, stating on their face "Drawn under Credit Suisse, Irrevocable Direct-Pay Letter of Credit No. ________________ Caribbean Regional Development March 8, 1994 Investment Trust Letter of Credit No. __________ Page 2 and accompanied by your written and completed certificate substantially in the form of ANNEX I, or ANNEX II, or ANNEX III attached hereto, as appropriate. All drawings under this Letter of Credit will be paid, in accordance with the terms and conditions of this Letter of Credit, with our own funds. Each Principal Drawing honored by us hereunder shall automatically and irrevocably reduce (i) the Principal Component (and the amount available to be drawn hereunder by subsequent Principal Drawings) by an amount equal to the amount of such Principal Drawing, and (ii) the Interest Component (and the amount available to be drawn hereunder by subsequent Interest Drawings) to an amount equal to 100 days accrued interest, at the rate of 10% per annum (computed as described below), on the then effective Principal Component; and such reductions shall automatically and irrevocably result in corresponding aggregate reductions in (A) the Stated Amount, and (B) the amount available to be drawn hereunder by a subsequent Final Drawing. Each Interest Drawing honored by us hereunder shall automatically reduce the Interest Component (and the amount available to be drawn hereunder by subsequent Interest Drawings) by an amount equal to the amount of such Interest Drawing; and such reduction shall automatically result in corresponding reductions in (i) the Stated Amount, and (ii) the amount available to be drawn hereunder by a subsequent Final Drawing. If you shall not have received from us, within 4 calendar days after the honoring by us of any Interest Drawing notice to the effect that we have not been reimbursed for such Interest Drawing or that any other "Event of Default" has occurred and is continuing under the Letter of Credit and Reimbursement Agreement, dated as of March 8, 1994 (the "Letter of Credit Agreement"), between the Account Party and us, pursuant to which this Letter of Credit is issued (such notice being the "Notice of Non-Reinstatement"), the Interest Component (and the amount available to be drawn hereunder by subsequent Interest Drawings) shall be automatically reinstated, effective on the 5th calendar day after the honoring by us of such Interest Drawing, to an amount equal to 100 days accrued interest at the rate of 10% per annum (computed as described below) on the then effective Principal Component. Each such reinstatement of the Interest Component (and the amount available to be drawn hereunder by subsequent Interest Drawings) shall automatically result in corresponding reinstatements of (A) the Stated Amount, and (B) the amount available to be drawn hereunder by a subsequent Final Drawing. In computing, as of any date, accrued interest on the then effective Principal Component, interest shall be computed for such amount at the rate of 10% per annum and on the basis of a year of 360 days and the actual number of days elapsed. Demand for payment may be made by you under this Letter of Credit at any time during our business hours at our address set forth below on a Business Day (as hereinafter defined). If a demand for payment is made by you under this Letter of Credit at or prior to 11:00 A.M., New York time, on a Business Day, and provided that such demand for payment Caribbean Regional Development March 8, 1994 Investment Trust Letter of Credit No. __________ Page 3 and the documents presented in connection therewith conform to the terms and conditions hereof, payment shall be made to you, in accordance with your payment instructions, of the amount demanded, in immediately available funds, not later than 4:00 P.M., New York time, on the same Business Day. If a demand for payment if made by you under this Letter of Credit after 11:00 A.M., New York time, on a Business Day, and provided such demand for payment and the documents presented in connection therewith conform to the terms and conditions hereof, payment shall be made to you, in accordance with your payment instructions, of the amount demanded, in immediately available funds, not later than 4:00 P.M., New York time, on the next succeeding Business Day. Payment under this Letter of Credit shall be made by wire transfer of Federal Reserve Bank of New York funds to your account at a bank on the Federal Reserve wire system or by deposit of same day funds into a designated account that you maintain with us. As used in this Letter of Credit the term "Business Day" shall mean any day that is not (i) a Saturday, (ii) a Sunday or (iii) another day on which commercial banks in the City of New York, New York, Port of Spain, Trinidad, or San Juan, Puerto Rico are authorized or required by law or executive order to close. If a demand for payment made by you under this Letter of Credit does not, in any instance, conform to the terms and conditions of this Letter of Credit, we shall give you prompt notice that such demand for payment was not effected in accordance with the terms and conditions of this Letter of Credit, stating the reasons therefor and that we are holding any documents at your disposal or are returning the same to you as you may elect. Upon being notified that a demand for payment made by you under this Letter of Credit was not effected in conformity with this Letter of Credit, you may attempt to correct such nonconforming demand for payment if, and to the extent that you are entitled (without regard to the provisions of this sentence) and able to do so. This Letter of Credit shall expire at 4:00 P.M., New York time, on the earliest to occur of the following dates (the "Termination Dates"): (i) May 11, 1998, (ii) the date on which you surrender this Letter of Credit to us, accompanied by your written statement certifying that the Loan has been paid in full (or provision has been made for such payment) or are otherwise no longer entitled to the benefits of this Letter of Credit; (iii) the date which is the 7th calendar day after the date on which you receive notice from us to the effect that this Letter of Credit is terminated by reason of occurrence and continuance of an "Event of Default" under the Letter of Credit Agreement (such notice being the "Notice of Termination"); and (iv) the date on which we honor your Final Drawing hereunder. Only you may make a drawing under this Letter of Credit. Upon the payment to you, in accordance with your payment instructions, of the amount specified in any draft drawn under this Letter of Credit, we shall be fully discharged of our obligation under this Letter of Credit in respect of such draft, to you or to any other person (including the holder of the Loan) who may have made to you or the Account Party or makes to you or to the Account Party a demand for payment with respect to the Loan. Caribbean Regional Development March 8, 1994 Investment Trust Letter of Credit No. __________ Page 4 This Letter of Credit sets forth in full our undertaking, and such undertaking shall not in any way be modified, amended, amplified or limited by reference to any document, instrument or agreement referred to herein (including, without limitation, the Letter of credit Agreement and the Loan), except for the drafts and the certificates referred to herein; and any such reference shall not be deemed to incorporate herein by reference any document, instrument or agreement except for such drafts and certificates. References to this Letter of Credit include the certificates attached hereto. This Letter of Credit shall be governed by the laws of the State of New York including, without limitation, Article 5 of the Uniform Commercial Code as in effect in the State of New York and the Uniform Customs and Practice for Documentary Credits in effect on the date of the issue of this Letter of Credit. All demands for payment under this Letter of Credit, as well as all notices and other communications to us with respect to this Letter of Credit, shall be in writing and shall be addressed to us at One Liberty Plaza, New York, New York 10006, Attention: Letter of Credit Department, or by facsimile to our facsimile number (212) 238-2121, or at any other office of facsimile number in New York, New York which may be designated by us by written notice delivered to you. Very truly yours, CREDIT SUISSE, a Swiss banking corporation, acting through its New York Branch By: Name: Title: By: Name: Title: Annex I to Irrevocable Direct-Pay Letter of Credit INTEREST DRAWING CERTIFICATE Reference is made to that certain Irrevocable Direct-Pay Letter of Credit No. _____________ dated March 8, 1994 (the "LETTER OF CREDIT"), in the face amount of $31,861,111.11 issued by Credit Suisse, a Swiss banking corporation, acting through its New York Branch for the account of Enron Gas & Oil Trinidad Limited ( the "COMPANY") and for the benefit of Caribbean Regional Development Investment Trust (the "BENEFICIARY"). The undersigned, a duly authorized representative of the Beneficiary, hereby certifies that: 1. The Beneficiary is making a demand for payment under the Letter of Credit with respect to the payment of interest accrued on the Loan which is due and payable on ________________ (the "Payment Date"). 2. The amount of the draft accompanying this Certificate (i) represents $_______________ being drawn by the Beneficiary under the Letter of Credit with respect to the payment of the account of interest accrued on the Loan which is due on the Payment Date, (ii) was computed in accordance with the provisions of the Loan, (iii) does not exceed the amount of the Interest Component or the amount available to be drawn under the Letter of Credit by Interest Drawings as in effect on the Payment Date, and (iv) has not been and is not the subject of a prior or contemporaneous demand for payment under the Letter of Credit. Annex I to Irrevocable Direct-Pay Letter of Credit INTEREST DRAWING CERTIFICATE Page Two The Beneficiary hereby acknowledges that, pursuant to the terms of the Letter of Credit, (A) the honoring by the Bank of the Interest Drawing made by this Certificate shall automatically reduce the Interest Component to $_______________ and the amount available to be drawn under the Letter of Credit by subsequent Interest Drawings to $_________________ (such reduction being in an amount equal to the amount of the draft accompanying this Certificate, as set forth in clause (i) of paragraph (2) of this Certificate); and (B) such reduction shall automatically result in corresponding reductions in (i) the Stated Amount, and (ii) the amount available to be drawn under the Letter of Credit by a subsequent Final Drawing. The Interest Component and the amount available to be drawn under the Letter of Credit in subsequent Interest Drawings are subject to reinstatement pursuant to the terms of the Letter of Credit. IN WITNESS WHEREOF, the Beneficiary has executed and delivered this Certificate as of the ______ day of ____________________. CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: Printed Name: Title: Annex II to Irrevocable Direct-Pay Letter of Credit PRINCIPAL DRAWING CERTIFICATE Reference is made to that certain Irrevocable Direct-Pay Letter of Credit No. _____________ dated March 8, 1994 (the "LETTER OF CREDIT"), in the face amount of $31,861,111.11 issued by Credit Suisse, a Swiss banking corporation, acting through its New York Branch for the account of Enron Gas & Oil Trinidad Limited ( the "COMPANY") and for the benefit of Caribbean Regional Development Investment Trust (the "BENEFICIARY"). The undersigned, a duly authorized representative of the Beneficiary, hereby certifies that: 1. The Beneficiary is making a demand for payment under the Letter of Credit with respect to the payment of interest accrued on the Loan which is due and payable on ________________ (the "Payment Date"). 2. The amount of the draft accompanying this Certificate (i) represents $______________, being drawn by the Beneficiary under the Letter of Credit with respect to the payment of the account of interest accrued on the Loan which is due on the Payment Date, (ii) was computed in accordance with the provisions of the Loan, (iii) does not exceed the amount of the Interest Component or the amount available to be drawn under the Letter of Credit by Interest Drawings as in effect on the Payment Date, and (iv) has not been and is not the subject of a prior or contemporaneous demand for payment under the Letter of Credit. Annex II to Irrevocable Direct-Pay Letter of Credit PRINCIPAL DRAWING CERTIFICATE Page Two The Beneficiary hereby acknowledges that, pursuant to the terms of the Letter of Credit, (A) the honoring by the Bank of the Principal Drawing made by this Certificate shall automatically and irrevocably reduce (1) the Principal Component to $___________________ and the amount available to be drawn under the Letter of Credit by subsequent Principal Drawings to $______________________ (such reduction being in an amount equal to the amount of such Principal Drawing, as set forth in clause (i) of paragraph (2) of this Certificate), and (2) the Interest Component and the amount available to be drawn under the Letter of Credit by subsequent Interest Drawings to an amount equal to $________________________ (100 days accrued interest computed as provided in the Letter of Credit) on the then effective Principal Component; and (B) such reductions shall automatically and irrevocably result in corresponding aggregate reductions in (i) the Stated Amount to $______________________, and (ii) the amount available to be drawn under the Letter of Credit by a subsequent Final Drawing to $______________________. IN WITNESS WHEREOF, the Beneficiary has executed and delivered this Certificate as of the ______ day of __________________________. CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: Printed Name: Title: Annex III to Irrevocable Direct-Pay Letter of Credit FINAL DRAWING CERTIFICATE Reference is made to that certain Irrevocable Direct-Pay Letter of Credit No. _____________ dated March 8, 1994 (the "LETTER OF CREDIT"), in the face amount of $31,861,111.11 issued by Credit Suisse, a Swiss banking corporation, acting through its New York Branch for the account of Enron Gas & Oil Trinidad Limited (the "COMPANY") and for the benefit of Caribbean Regional Development Investment Trust (the "BENEFICIARY"). The undersigned, a duly authorized representative of the Beneficiary, hereby certifies that: 1. The Beneficiary is making a demand for payment under the Letter of Credit with respect to the payment, upon the acceleration of the principal of, and interest accrued on, the Loan which is due and payable on ___________________________ (the "Payment Date"). 2. The amount of the draft accompanying this Certificate (i) represents (a) $__________________, being drawn by the Beneficiary under the Letter of Credit with respect to the payment of the principal of the Loan which is due on the Payment Date, plus (b) $__________________, being drawn by the Beneficiary under the Letter of Credit with respect to the payment of interest accrued on the Loan which is due on the Payment Date, (ii) was computed in accordance with the provisions of the Loan, (iii) does not exceed the amount available for a Final Drawing under the Letter of Credit, and (iv) has not been and is not the subject of a prior or contemporaneous demand for payment under the Letter of Credit. Annex III to Irrevocable Direct-Pay Letter of Credit FINAL DRAWING CERTIFICATE Page Two 3. The aggregate amounts being drawn by the Beneficiary under the Letter of Credit with respect to the payment of principal of and interest accrued on the Loan, as set forth in sub-clauses (a) and (b) of clause (i) of paragraph (2) of the Certificate, do not exceed the respective amounts of the Principal Component and the Interest Component, in each case, as in effect on the Payment Date. IN WITNESS WHEREOF, the Beneficiary has executed and delivered this Certificate as of the ______ day of ___________________________. CARIBBEAN REGIONAL DEVELOPMENT INVESTMENT TRUST By: Printed Name: Title: EX-10.44 19 PARENT GUARANTY EXHIBIT 10.44 PARENT GUARANTY THIS PARENT GUARANTY (as the same may be amended or supplemented from time to time, this "GUARANTY") is made and entered into as of this 8th day of March, 1994, by ENRON OIL & GAS COMPANY, a Delaware corporation ("GUARANTOR"), in favor of CREDIT SUISSE, a Swiss banking corporation, acting through its New York Branch (the "BANK"). WHEREAS, pursuant to that certain Letter of Credit and Reimbursement Agreement dated as of the date hereof (as from time to time amended, supplemented or otherwise modified, the "REIMBURSEMENT AGREEMENT"), between Enron Gas & Oil Trinidad Limited (the "Obligor") and the Bank, the Bank has agreed to issue a letter of credit in the stated amount of $31,861,111.11 (the "Letter of Credit") for the account of the Obligor and for the benefit of Caribbean Regional Development Investment Trust; WHEREAS, Guarantor intends this Guaranty to be an inducement for the Bank to accept the terms of and enter into the Reimbursement Agreement and to issue the Letter of Credit, which the Bank would not be willing to do unless Guarantor executes and delivers this Guaranty; NOW, THEREFORE, for valuable consideration, the receipt and sufficiency of which are hereby acknowledged, and to induce the Bank to accept the terms of the Reimbursement Agreement and to issue the Letter of Credit, Guarantor, intending to be legally bound by this Guaranty, hereby agrees as follows: ARTICLE I DEFINITIONS AND ACCOUNTING TERMS Section 1.01. CERTAIN DEFINED TERMS. As used in this Agreement, the following terms shall have the following meanings (such meanings to be equally applicable to both the singular and plural forms of the terms defined): "BANKRUPTCY LAW" means Title 11 of the United States Code entitled "Bankruptcy" as now or hereinafter in effect, or any successor thereto. "BUSINESS DAY" means any day that is not (i) a Saturday, (ii) a Sunday, or (iii) another day on which (a) commercial banks in the City of New York, New York, Port of Spain, Trinidad, or San Juan, Puerto Rico are authorized or required by law or order to close or (b) the New York Stock Exchange is not open for trading. "CODE" means, as appropriate, the Internal Revenue Code of 1986, as amended, or any successor Federal tax code, and any reference to any statutory provision shall be deemed to be a reference to any successor provision or provisions. "CONSOLIDATED" refers to the consolidation of the accounts of Guarantor and its Subsidiaries in accordance with GAAP. "CREDIT AGREEMENT" means the Credit Agreement to be executed among Enron Oil & Gas Company, the banks named therein, and Texas Commerce Bank, N.A., as Administrative Agent, as such Credit Agreement is in effect on the date of execution thereof. "DEBT" shall have the meaning ascribed to such term in the Credit Agreement. "EVENTS OF DEFAULT" has the meaning specified in Section 5.01. "ERISA" means the Employee Retirement Income Security Act of 1974, as amended from time to time, and the regulations promulgated and rulings issued thereunder from time to time. "ERISA AFFILIATE" means any trade or business (whether or not incorporated) which is a member of a group of which Guarantor is a member and which is under common control within the meaning of the regulations under Section 414 of the Code. "GAAP" means generally accepted accounting principles, in effect from time to time, consistently applied. "GUARANTEED OBLIGATIONS" means all indebtedness, obligations, and liabilities of the Obligor to the Bank arising out of, under, or in connection with the Reimbursement Agreement and the Letter of Credit, and any and all legal and other expenses and costs incurred by the Bank in connection therewith or in connection with enforcing the Reimbursement Agreement or this Guaranty, and the due and punctual performance and observance by the Obligor of each and every agreement, covenant, and condition in the Reimbursement Agreement and the Letter of Credit. "GUARANTOR MATERIAL ADVERSE EFFECT" means a material adverse effect on (a) Guarantor and its Subsidiaries, taken as a whole, or (b) Guarantor's ability to perform its obligations under this Guaranty. "INSUFFICIENCY" means, with respect to any Plan, the amount, if any, by which the present value of the vested benefits under such Plan exceeds the fair market value of the assets of such Plan allocable to such benefits. "MULTIEMPLOYER PLAN" means a "multiemployer plan" as defined in Section 4001(a)(3) of ERISA to which Guarantor or any ERISA Affiliate is making or accruing an obligation to make contributions, or has within any of the preceding five plan years made or accrued an obligation to make contributions. "MULTIPLE EMPLOYER PLAN" means an employee benefit plan, other than a Multiemployer Plan, subject to Title IV of ERISA to which Guarantor or any ERISA Affiliate, and one or more employers other than Guarantor or an ERISA Affiliate, is making or accruing an obligation to make contributions during any of the five plan years preceding the date of termination of such plan. -2- "OPERATIVE DOCUMENTS" means the Reimbursement Agreement, the Letter of Credit, and any agreement, instrument, certificate, or document now or hereafter executed by the Obligor in connection with the obligations under the Reimbursement Agreement and the Letter of Credit. "PBGC" means the Pension Benefit Guaranty Corporation. "PERSON" means an individual, sole proprietorship, partnership, corporation, business trust, joint stock company, trust, unincorporated association, joint venture, not-for-profit corporation or other entity, sovereign government or agency, instrumentality, or political subdivision thereof. "PLAN" means an employee benefit plan (other than a Multiemployer Plan) which is (or, in the event that any such plan has been terminated within five years after a transaction described in Section 4069 of ERISA, was) maintained for employees of Guarantor or any ERISA Affiliate and covered by Title IV of ERISA. "PRINCIPAL SUBSIDIARY" means at any time of determination any Subsidiary having consolidated assets in excess of $100,000,000. For purposes of this definition, consolidated assets shall be determined based on the most recent quarterly or annual financial statements available prior to such determination. "SUBSIDIARY" means any corporation of which more than 50% of the outstanding capital stock having ordinary voting power to elect a majority of the board of directors of such corporation or others performing similar functions (irrespective of whether or not at the time capital stock of any class or classes of such corporation shall or might have voting power upon the occurrence of any contingency) is at the time directly or indirectly owned by Guarantor. "TERMINATION EVENT" means (i) a "reportable event", as such term is described in Section 4043 of ERISA (other than a "reportable event" not subject to the provision for 30-day notice to the PBGC), or an event described in Section 4062(e) of ERISA, or (ii) the withdrawal of Guarantor or any ERISA Affiliate from a Multiple Employer Plan during a plan year in which it was a "substantial employer", as such term is defined in Section 4001(a)(2) of ERISA, or the incurrence of liability by Guarantor or any ERISA Affiliate under Section 4064 of ERISA upon the termination of a Multiple Employer Plan, or (iii) the distribution of a notice of intent to terminate a Plan pursuant to Section 4041(a)(2) of ERISA or the treatment of a Plan amendment as a termination under Section 4041 of ERISA, or (iv) the institution of proceedings to terminate a Plan by the PBGC under Section 4042 of ERISA, or (v) any other event or condition which might constitute grounds under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan. "WITHDRAWAL LIABILITY" has the meaning set forth under Part I of Subtitle E of Title IV of ERISA. ARTICLE II THE GUARANTY -3- Section 2.01. GUARANTY. (a) Guarantor hereby absolutely, irrevocably, and unconditionally guarantees to the Bank the due and punctual payment and performance of all of the Guaranteed Obligations, whether at maturity, at any stated prepayment date or earlier, by reason of acceleration, or otherwise. (b) If for any reason whatsoever an event of default under the Operative Documents occurs and the Obligor shall fail or be unable duly, punctually, and fully to pay or perform any of the Guaranteed Obligations, then Guarantor shall pay or cause to be paid to the Bank, or perform or cause to be performed pursuant to the terms of the Operative Documents, the Guaranteed Obligations. Section 2.02. GUARANTOR'S OBLIGATION UNCONDITIONAL. The obligations of Guarantor hereunder shall be absolute and unconditional, irrespective of (a) the validity, regularity or enforceability of the Operative Documents or of the obligations thereunder, (b) any present or future law or order of any government (whether of right or in fact) or of any agency thereof purporting to reduce, amend or otherwise affect any obligation of the Obligor or to vary the terms of payment, (c) any action taken by the Bank in the exercise of any right, power or remedy or any failure or omission to enforce any right, power or remedy, and (d) any other circumstance whatsoever (with or without notice to or knowledge of Guarantor) which may or might in any manner or to any extent vary the risks of Guarantor hereunder or otherwise constitute a legal or equitable discharge of a surety or Guarantor, it being the intent of Guarantor that this Guaranty and Guarantor's obligations shall be absolute and unconditional under any and all circumstances and shall not be discharged except by final payment and performance of the Guaranteed Obligations. Section 2.03. CONSENT. From time to time, without notice to or further consent of Guarantor and without affecting the liability of Guarantor hereunder, Guarantor hereby agrees that (and consents to) (a) any of the Guaranteed Obligations may be extended or renewed in whole or in part, (b) any payment, performance or observance by the Obligor may be waived, modified or extended in whole or in part, (c) any other indulgence may be granted by the Bank, (d) the payment or any obligation may be accelerated in accordance with any agreement between the Obligor and the Bank, and (e) any other guaranty, collateral or other security for any financial accommodation may be exchanged, surrendered, or otherwise dealt with as the Bank may determine. Section 2.04. WAIVERS OF NOTICE. Guarantor hereby waives notice of acceptance of this Guaranty and of the granting of any financial accommodation and further waives any requirement of diligence or promptness, notice of default by the Obligor, any and all presentment, demand of payment, protest or notice of nonpayment or protest or of the exchange, sale, surrender or other handling or disposition of any other guaranty, collateral or other security, any requirement that the Bank exhaust any right, power or remedy or proceed against the Obligor under any of the Operative Documents or against any other Person under any other guaranty of, or security for, any of the Guaranteed Obligations, and any and all other notices and demands whatsoever. -4- Section 2.05. WAIVERS OF DEFENSE. To the fullest extent permitted by law, Guarantor unconditionally waives any defenses based upon any legal disability of the Obligor whether (i) consensual, (ii) arising by operation of law, (iii) as a result of any bankruptcy, insolvency or debtor-relief proceeding, or (iv) from any other cause. Guarantor further waives any duty of the Bank to advise Guarantor of any information known to the Bank regarding the financial condition of the Obligor and all other circumstances affecting the Obligor's ability to perform its obligations to the Bank, it being agreed that Guarantor assumes the responsibility for being and keeping informed regarding such condition or any such circumstances. Section 2.06. NO SUBROGATION; BANKRUPTCY; NO DISCHARGE. (a) GUARANTOR HEREBY WAIVES ANY AND ALL RIGHTS OF SUBROGATION, INDEMNITY, CONTRIBUTION, OR REIMBURSEMENT IN RESPECT OF THE GUARANTEED OBLIGATIONS; ANY BENEFIT OF, OR RIGHT TO ENFORCE ANY REMEDY THAT THE BANK NOW HAS OR MAY HEREAFTER HAVE AGAINST THE OBLIGOR IN RESPECT OF THE OBLIGATIONS OR AGAINST ANY PROPERTY NOW OR HEREAFTER HELD BY THE BANK AS SECURITY FOR THE GUARANTEED OBLIGATIONS; AND ANY AND ALL SIMILAR RIGHTS GUARANTOR MAY HAVE AGAINST THE OBLIGOR UNDER APPLICABLE LAW OR OTHERWISE IN RESPECT OF THE GUARANTEED OBLIGATIONS. If, notwithstanding the foregoing, any amount shall be paid to Guarantor on account of any such subrogation, indemnity, contribution, or reimbursement rights in respect of the Guaranteed Obligations, then such amount shall be held in trust for the benefit of the Bank and shall forthwith be paid to the Bank to be credited and applied against the Guaranteed Obligations, whether matured, unmatured, absolute, or contingent, as the Bank may see fit in its discretion. (b) Notwithstanding anything to the contrary contained herein, this Guaranty shall continue to be effective or be reinstated, as the case may be, if at any time payment, or any part thereof, of any or all of the Guaranteed Obligations are rescinded, invalidated, declared to be fraudulent or preferential, or otherwise required to be restored or returned by the Bank or any other Person upon the insolvency, bankruptcy or reorganization of the Obligor or otherwise, or if the proceeds of any collateral are required to be returned by the Bank or any other Person under any circumstances or if the Bank or any other Person elect to return such payment or proceeds or any part thereof in its sole discretion, all as though such payment or application of proceeds had not been made. Without limiting the generality of the foregoing, if prior to any such rescission, invalidation, declaration, restoration, or return, this Guaranty shall have been canceled or surrendered, then this Guaranty shall be reinstated in full force and effect, and such prior cancellation or surrender shall not diminish, release, discharge, impair, or otherwise affect the obligations of Guarantor in respect of the amount of the affected payment or application of proceeds. (c) Notwithstanding (i) any modification, discharge, or extension of the Guaranteed Obligations; (ii) any disallowance of all or any portion of the Bank's or any other Person's claim for repayment of the Guaranteed Obligations; (iii) any use of cash or other collateral in any bankruptcy or reorganization case; (iv) any agreement or stipulation as to adequate protection in any bankruptcy or reorganization case; (v) any failure by the Bank or any other Person to file or enforce a claim against the Obligor or the Obligor's estates in any -5- bankruptcy or reorganization case; or (vi) any amendment, modification, stay, or cure of the Bank's, the Obligor's, or any other Person's rights that may occur in any bankruptcy or reorganization case or proceeding concerning the Obligor, whether permanent or temporary, and whether assented to by the Bank, the Obligor, or any other Person, Guarantor hereby agrees that Guarantor shall be obliged hereunder to pay the Guaranteed Obligations and discharge Guarantor's other obligations in accordance with the terms of the Guaranteed Obligations and the terms of this Guaranty. Section 2.07. SUBORDINATION. Guarantor hereby agrees that any and all present and future debts and obligations of the Obligor to Guarantor and any and all claims of Guarantor against the Obligor, or any of its properties, howsoever arising, shall be subordinate and subject in right of payment to the prior payment, in full, of the Guaranteed Obligations. Section 2.08. CERTAIN RIGHTS AND POWERS OF THE BANK. (a) The Bank may proceed to protect and enforce any or all of its rights by suit in equity or action at law, or by other appropriate proceedings, whether for the specific performance of any covenants or agreements contained in the Operative Documents or to take any action authorized or permitted under applicable law. Each and every remedy of the Bank shall, to the extent permitted by law, be cumulative and shall be in addition to any other remedy given hereunder or under the Operative Documents or now or hereafter existing at law or in equity. (b) At the option of the Bank, Guarantor may be joined in any action or proceeding commenced by the Bank in connection with or based on any of the Operative Documents or any of the transactions contemplated thereby, and recovery may be had against Guarantor in such action or proceeding or in any independent action or proceeding against Guarantor, without any requirement that the Bank first assert, prosecute, or exhaust any remedy or claim against the Obligor or any collateral security or guaranty in respect of the Guaranteed Obligations. ARTICLE III REPRESENTATIONS AND WARRANTIES Section 3.01. Guarantor hereby represents and warrants to the Bank that the following statements shall be true and correct on and as of the Closing Date: (a) ORGANIZATION AND AUTHORITY. Guarantor has the requisite corporate power, authority, and legal right to execute, deliver and perform this Guaranty, and Guarantor has taken all necessary corporate action to authorize the execution, delivery and performance of this Guaranty. This Guaranty violates no contractual provisions entered into by Guarantor, nor any law. No consent of any other Person (including, without limitation, stockholders or creditors of Guarantor), and no consent, license, permit, approval or authorization of, exemption by, filing, or declaration with, any governmental authority, is required in connection with the execution, delivery, performance, validity or enforceability of this Guaranty by or against -6- Guarantor. This Guaranty has been duly executed and delivered by Guarantor, and this Guaranty constitutes the legal, valid, and binding obligation of Guarantor enforceable against it in accordance with its terms. (b) FINANCIAL STATEMENTS. The audited Consolidated balance sheet of Guarantor and its Subsidiaries as of December 31, 1992, and the related audited Consolidated statements of income, cash flows and changes in shareholders' equity accounts of Guarantor for the fiscal year ended on said date and the unaudited Consolidated balance sheet of the Guarantor and its Subsidiaries as of September 30, 1993, and the related unaudited Consolidated statements of income, cash flows and changes in shareholders' equity accounts for the fiscal quarter then ended, present fairly, in conformity with GAAP, the Consolidated financial condition of Guarantor and its Subsidiaries at the date of said statements and the Consolidated results of the operations of Guarantor and its Subsidiaries for said fiscal periods. Since December 31, 1992, there has been no material adverse change in the Consolidated financial position, or Consolidated results of operations of Guarantor and its Subsidiaries considered as a whole or Guarantor's ability to perform its obligations under the Operative Documents or other credit agreements to which it is a party. (c) PENDING LITIGATION. Except as disclosed in Guarantor's Form 10-K for the year ended December 31, 1992 or the Guarantor's Form 10-Q for each of the quarters ended March 31, 1993, June 30, 1993 and September 30, 1993, there is no action, suit, or proceeding pending against Guarantor or any of its Subsidiaries or, to the knowledge of Guarantor, threatened against Guarantor or any of its Subsidiaries, before any court or arbitrator or any governmental body, agency, or official in which there is a reasonable possibility of an adverse decision which would materially adversely affect the Consolidated financial position, or Consolidated results of operations of Guarantor and its Subsidiaries taken as a whole, or which could reasonably be expected to have a Guarantor Material Adverse Effect. (d) SUBSIDIARIES. Each of the Subsidiaries (including, without limitation, the Obligor) is a corporation duly incorporated, validly existing, and in good standing under the laws of its jurisdiction of incorporation. Each of the Subsidiaries has all corporate powers and all governmental licenses, authorizations, consents, and approvals required to carry on its business as now conducted, except where such failures to have such licenses, authorizations, consents, and approvals could not, in the aggregate, reasonably be expected to have a Guarantor Material Adverse Effect. (e) ENFORCEABILITY. This Guaranty is legal, valid, and binding obligation, enforceable against Guarantor in accordance with its terms, except as the enforceability thereof may be limited by the effect of any applicable bankruptcy, insolvency, reorganization, moratorium, or similar laws affecting creditors' rights generally and by general principles of equity. (f) NO DEFAULT. No event has occurred and no condition exists which, with the giving of notice or the passage of time, or both, would constitute an Event of Default. (g) CONSENTS. The execution, delivery and performance by Guarantor of this Guaranty does not require the consent or the approval or authorization of, or filing, registration, -7- or qualification with, any Person or any Federal, state, or local government on the part of Guarantor as a condition to such execution, delivery, consummation, and compliance. (h) ERISA. No Termination Event has occurred or is reasonably expected to occur with respect to any Plan for which an Insufficiency in excess of $50,000,000 exists. Neither Guarantor nor any ERISA Affiliate has received any notification that any Multiemployer Plan is in reorganization or has been terminated, within the meaning of Title IV of ERISA, and Guarantor is not aware of any reason to expect that any Multiemployer Plan is to be in reorganization or to be terminated within the meaning of Title IV of ERISA, for which a Withdrawal Liability in excess of $50,000,000 exists. (i) TAXES. United States Federal income tax returns of Guarantor and its Subsidiaries have been examined and closed through the fiscal year ended December 31, 1987. Guarantor and its Subsidiaries have filed all United States Federal income tax returns and all other material domestic tax returns which to the knowledge of Guarantor are required to be filed by them and have paid or provided for the payment before the same become delinquent of all taxes shown to be due on such returns or pursuant to any assessment received by Guarantor or any Subsidiary, other than those taxes contested in good faith by appropriate proceedings. The charges, accruals and reserves on the books of Guarantor and its Subsidiaries in respect of taxes are, in the opinion of Guarantor, adequate to the extent required by GAAP. (j) STATUS. (i) Neither Guarantor nor any of its Subsidiaries is or is controlled by an "investment company" within the meaning of the Investment Company Act of 1940, as amended; and (ii) Neither Guarantor nor any Principal Subsidiary is a "holding company", a "subsidiary company" of a "holding company", an "affiliate" of a "holding company", or an "affiliate" of a "subsidiary company" of a "holding company", in each case as such term is defined in the Public Utility Holding Company Act of 1935, as amended. ARTICLE IV COVENANTS Section 4.01. GUARANTOR'S AFFIRMATIVE COVENANTS. Guarantor covenants and agrees with the Bank that so long as any of the Operative Documents shall remain in effect or any Guaranteed Obligations shall remain unsatisfied, Guarantor will: (a) COMPLIANCE WITH LAWS, ETC. Comply, and cause each of the Subsidiaries to comply, with all applicable laws, rules, regulations and orders to the extent noncompliance therewith would have a material adverse effect on the assets or business of Guarantor and the Subsidiaries taken as a whole, such compliance to include, without limitation, paying before the same become delinquent all taxes, assessments and governmental charges imposed upon it or upon its property except to the extent contested in good faith. -8- (b) REPORTING REQUIREMENTS. Furnish to the Bank: (i) as soon as available and in any event within 75 days after the end of each of the first three quarters of each fiscal year of Guarantor, a copy of Guarantor's quarterly report on Form 10-Q for such quarter as filed with the Securities and Exchange Commission, which report will include Guarantor's quarterly unaudited financial statements as of the end of and for such quarter; (ii) as soon as available and in any event within 135 days after the end of each fiscal year of Guarantor, a copy of the annual report on Form 10-K for such year for Guarantor as filed with the Securities and Exchange Commission, which annual report will include Guarantor's annual audited Consolidated financial statements as of the end of and for such year; (iii) simultaneously with the delivery of each of the annual or quarterly reports referred to in clauses (i) and (ii) above, a certificate of the chief financial officer or the chief accounting officer of Guarantor in a form acceptable to the Bank (x) setting forth in reasonable detail the calculations required to establish whether Guarantor was in compliance with the requirements of Section 4.01(g) on the date of the financial statements contained in such report, and (y) stating whether there exists on the date of such certificate any Event of Default or event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default, and, if so, setting forth the details thereof and the action which Guarantor has taken and proposes to take with respect thereto; (iv) as soon as possible and in any event within five days after an executive officer of Guarantor becomes aware of the occurrence of each Event of Default and each event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default, continuing on the date of such statement, a statement of the chief financial officer of Guarantor setting forth details of such Event of Default or event and the action which Guarantor has taken and proposes to take with respect thereto; (v) promptly after the sending or filing thereof, copies of all reports which Guarantor sends to any of its public securityholders, and copies of all reports on Forms 10-K, 10-Q and 8-K (or any comparable form) and registration statements (other than registration statements relating to stock options or other employee benefit plans or to secondary offerings of securities and excluding the exhibits relating to any registration statement) which Guarantor files with the Securities and Exchange Commission or any national securities exchange; (vi) as soon as possible and in any event (A) within 30 Business Days after Guarantor or any ERISA Affiliate knows or has reason to know that any Termination Event described in clause (i) of the definition of Termination Event -9- with respect to any Plan for which an Insufficiency in excess of $50,000,000 exists, has occurred and (B) within 10 Business Days after Guarantor or any ERISA Affiliate knows or has reason to know that any other Termination Event with respect to any Plan for which an Insufficiency in excess of $50,000,000 exists, has occurred or is reasonably expected to occur, a statement of the chief financial officer or chief accounting officer of Guarantor describing such Termination Event and the action, if any, which Guarantor or such ERISA Affiliate proposes to take with respect thereto; (vii) promptly and in any event within five Business Days after receipt thereof by Guarantor or any ERISA Affiliate, copies of each notice received by Guarantor or any ERISA Affiliate from the PBGC stating its intention to terminate any Plan for which an Insufficiency in excess of $50,000,000 exists, or to have a trustee appointed to administer any Plan for which an Insufficiency in excess of $50,000,000 exists; (viii) promptly and in any event within five Business Days after receipt thereof by Guarantor or any ERISA Affiliate from the sponsor of a Multiemployer Plan, a copy of each notice received by Guarantor or any ERISA Affiliate indicating liability in excess of $50,000,000 incurred or expected to be incurred by Guarantor or any ERISA Affiliate in connection with (A) the imposition of a Withdrawal Liability by a Multiemployer Plan, (B) the determination that a Multiemployer Plan is, or is expected to be, in reorganization within the meaning of Title IV of ERISA, (C) the termination of a Multiemployer Plan within the meaning of Title IV of ERISA; (ix) such other information respecting the condition or operations, financial or otherwise (including an annual report or reports on oil and gas reserves of Guarantor and the Subsidiaries), of Guarantor as the Bank may from time to time reasonably request. (c) MAINTENANCE OF INSURANCE. Maintain, and cause each of the Principal Subsidiaries to maintain insurance with responsible and reputable insurance companies or associations in such amounts and covering such risks as is usually carried by companies engaged in similar businesses and owning similar properties in the same general areas in which Guarantor or such Principal Subsidiary operates, provided that self-insurance by Guarantor or any such Principal Subsidiary shall not be deemed a violation of this covenant to the extent that companies engaged in similar businesses and owning similar properties in the same general areas in which Guarantor or such Principal Subsidiary operates self-insure. Guarantor may maintain its Principal Subsidiaries' insurance on behalf of them. (d) PRESERVATION OF CORPORATE EXISTENCE, ETC. Preserve and maintain, and cause each of the Principal Subsidiaries to preserve and maintain, its corporate existence, rights (charter and statutory), and franchises; PROVIDED, HOWEVER, that this Section 4.01(d) shall not apply to any transactions permitted by Section 4.02(a) and shall not prevent the termination of existence, rights and franchises of any Principal Subsidiary pursuant to any merger or consolidation to which such Principal Subsidiary is a party; and provided, further, that Guarantor or any Principal Subsidiary shall not be required to preserve any right or franchise if Guarantor or such Principal Subsidiary shall determine that the preservation thereof is no longer desirable in the conduct of the business of Guarantor or such Principal Subsidiary, as the case may be, and that the loss thereof is not disadvantageous in any material respect to the Bank. -10- (e) VISITATION RIGHTS. At any reasonable time and from time to time, after reasonable notice, permit the Bank to examine the records and books of account of, and visit the properties of Guarantor and to discuss the affairs, finances and accounts of Guarantor with any of their respective officers or directors. (f) DEBT TO CAPITALIZATION RATIO. Maintain at all times a ratio of (i) Total Debt (as such term is defined in the Credit Agreement) to (ii) Total Capitalization (as such term is defined in the Credit Agreement) equal to or less than 0.5. Section 4.02. NEGATIVE COVENANTS. Guarantor covenants and agrees with the Bank that so long as any of the Operative Documents shall remain in effect or any Guaranteed Obligations shall remain unsatisfied, Guarantor will not: (a) MERGERS, ETC. Merge or consolidate with or into, or permit any Principal Subsidiary to merge or consolidate with or into, any Person, unless (i) in the case of Guarantor, Guarantor is the surviving corporation and is not a Subsidiary of any other Person other than Enron Corp., or (ii) in the case of any Principal Subsidiary, Guarantor or, if Guarantor is not a party to such merger or consolidation, a Subsidiary of Guarantor, in which the interest owned, directly or indirectly, by Guarantor is at least equal to the interest owned, directly or indirectly, by Guarantor in the merging or consolidating Subsidiary is the surviving or resulting corporation, provided in each case referred to in clause (i) or (ii) of this sentence that, immediately after giving effect to such proposed transaction, no Event of Default or event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default would exist. (b) COMPLIANCE WITH ERISA. (i) Terminate, or permit any ERISA Affiliate to terminate, any Plan so as to result in any liability of Guarantor or any ERISA Affiliate to the PBGC in excess of $50,000,000, or (ii) permit circumstances which give rise to a Termination Event described in clause (ii), (iv) or (v) of the definition of Termination Event with respect to a Plan so as to result in any liability in excess of $50,000,000 of Guarantor or any ERISA Affiliate to PBGC. Section 4.03. COMPLIANCE WITH COVENANTS UNDER CREDIT AGREEMENT. Guarantor will not fail to perform or observe any term, covenant, or agreement contained in Sections 5.01 and 5.02 of the Credit Agreement. The terms, covenants, and agreements in Section 5.01 and 5.02 shall have the same force and effect as if fully recited herein, shall be deemed to have been made in favor of the Bank, shall survive the termination or expiration of the Credit Agreement (or Guarantor's obligations thereunder) and, notwithstanding any such termination or expiration of the Credit Agreement (or Guarantor's obligations thereunder), shall continue to inure to the benefit of the Bank. Any amendment or modification to any of the terms, covenants, or agreements contained in Sections 5.01 and 5.02 of the Credit Agreement shall not be operative and shall have no force and effect with respect to Guarantor and the Bank pursuant to this Guaranty and such terms, covenants, and agreements contained in Sections 5.01 and 5.02 shall be deemed to remain as written, without regard to any such amendment or modification. -11- ARTICLE V EVENTS OF DEFAULT Section 5.01. EVENT OF DEFAULT. If any of the following events shall occur it shall constitute an "EVENT OF DEFAULT" hereunder: (a) Guarantor shall fail to observe or perform any covenant or agreement contained in this Guaranty; (b) Guarantor shall fail to maintain, or cause to be maintained, the validity and effectiveness of each Operative Document; (c) Guarantor or any of its Principal Subsidiaries shall generally not pay its debts as such debts become due, or shall admit in writing its inability to pay it debts generally, or shall make a general assignment for the benefit of creditors; or any proceeding shall be instituted by or against Guarantor or any of its Principal Subsidiaries seeking to adjudicate it as bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief, or composition of it or its debts under any Bankruptcy Law or seeking the entry of an order for relief or the appointment of a receiver, trustee, or other similar official for it or for any substantial part of its property and, in the case of any such proceeding instituted against it (but not instituted by it), shall remain undismissed or unstayed for a period of 60 days; (d) Guarantor or any of its Principal Subsidiaries shall take any corporate action to authorize any of the actions set forth above in Section 5.01(c); (e) (i) Any Debt which is outstanding in a principal amount of at least $50,000,000 in the aggregate of Guarantor or any of its Principal Subsidiaries shall be declared to be due and payable, or required to be prepaid (other than by a regularly scheduled required prepayment or as a result of the giving of notice of voluntary prepayment), prior to the stated maturity thereof; or (ii) Any other event shall occur or condition shall exist under any agreement or instrument relating to any Debt which is outstanding in a principal amount of at least $50,000,000 in the aggregate of Guarantor or any of its Principal Subsidiaries and shall continue after the applicable grace period, if any, specified in such agreement or instrument, if the maturity of such Debt is accelerated as a result of the effect of such event or condition; or (f) (i) Any Termination Event as defined in clause (ii), (iv) or (v) of the definition thereof with respect to a Plan shall have occurred and, 30 days after notice thereof shall have been given to Guarantor by the Bank, (A) such Termination Event shall still exist and (B) the sum (determined as of the date of occurrence of such Termination Event) of the liabilities to the PBGC resulting from all such Termination Events is equal to or greater than $100,000,000; or -12- (ii) Guarantor or any ERISA Affiliate shall have been notified by the sponsor of a Multiemployer Plan that it has incurred Withdrawal Liability to such Multiemployer Plan in an amount which, when aggregated with all other amounts required to be paid to Multiemployer Plans in connection with Withdrawal Liabilities (determined as of the date of such notification), exceeds $100,000,000 or requires payments exceeding $50,000,000 per annum; or (iii) Guarantor or any ERISA Affiliate shall have been notified by the sponsor of a Multiemployer Plan that such Multiemployer Plan is in reorganization or is being terminated, within the meaning of Title IV of ERISA, if as a result of such reorganization or termination the aggregate annual contributions of the Guarantor and its ERISA Affiliates to all Multiemployer Plans which are then in reorganization or being terminated have been or will be increased over the amounts contributed to such Multiemployer Plans for the respective plan years which include the date hereof by an amount exceeding $50,000,000 in the aggregate; or (g) Any judgment, decree or order for the payment of money in excess of $50,000,000 shall be rendered against Guarantor or any of its Principal Subsidiaries and remains unsatisfied and either (i) enforcement proceedings shall have been commenced by any creditor upon such judgment, decree, or order, or (ii) there shall be any period of 60 consecutive days during which a stay of enforcement of such judgment, decree, or order, by reason of a pending appeal or otherwise, shall not be in effect; or (h) Any representation or warranty of Guarantor set forth herein or in any Operative Document or in any certificate, notice, demand, request, or other document delivered to the Bank in connection herewith or therewith shall prove to have been incorrect in any material respect when made or deemed made and such materiality is continuing. Section 5.02. WAIVER OF DEFAULT. No waiver by the Bank of any Event of Default shall in any way be, or be construed to be, a waiver of any further or subsequent Event of Default. ARTICLE VI MISCELLANEOUS Section 6.01. TERM OF GUARANTY. This Guaranty and all guarantees, covenants, and agreements of Guarantor contained herein shall continue in full force and effect and shall not be discharged until such time as all of the obligations of Guarantor hereunder and all of the obligations (including the Guaranteed Obligations) of the Obligor under the Operative Documents shall be duly and completely paid or performed. Section 6.02. SUCCESSORS AND ASSIGNS. This Guaranty shall continue in full force and effect and be binding upon Guarantor and the successors and assigns of Guarantor notwithstanding the release of Guarantor or any other party liable upon or in respect of the Guaranteed Obligations. Guarantor may not assign or otherwise transfer this instrument or any obligations hereunder without the prior written consent of the Bank. The Bank may assign this Guaranty or any rights or powers hereunder, with any or all of the underlying liabilities or obligations the payment of which is guaranteed hereunder. As used in this Guaranty, the term -13- "Bank" shall in all respects mean and include CREDIT SUISSE, NEW YORK BRANCH and its successors, assigns, or participants. Section 6.03. PARAGRAPH HEADINGS. THE paragraph headings inserted in this Guaranty have been included for convenience only and are not intended, and shall not be construed, to limit or define in any way the substance of any paragraph contained herein. Section 6.04. NOTICES. Except where otherwise provided herein, all instructions, notices and other communications to be given to any party hereto shall be in writing and shall be personally delivered or sent by first-class mail, or by telecopier, and shall be deemed to be given for purposes of this Guaranty on the day when delivered or sent (except if sent by certified mail they shall be deemed to be given on the 5th Business Day after the day on which mailed) to the intended party at its address or telecopier number specified below (or as such party may specify to the other parties in writing). Any requirement that notice be given to any person under this Guaranty shall be deemed to require notice to every person listed below. The addresses of the Bank and Guarantor for notices are: If to Bank: Credit Suisse 12 E. 49th Street New York, New York 10017 Attention: Hazel Leslie Telephone: (212) 612-8055 Telecopier: (212) 612-8368 with a copy to:Credit Suisse Houston Representative Office 1100 Louisiana, Suite 4750 Houston, Texas 77002 Attention: Donald W. Herrick, Jr. Vice President Telephone: (713) 751-0300 Telecopier: (713) 751-0702 If to Guarantor:Enron Oil & Gas Company 1400 Smith Street Houston, Texas 77002 Attention: Senior Vice President and Chief Financial Officer Telephone: (713) 853-5012 Telecopier: (713) 646-8062 Any party may change its address for purposes of this Agreement by giving notice of such change to the other parties pursuant to this Section 6.04. Section 6.05. AMENDMENTS AND WAIVERS. Neither this Guaranty nor any term hereof may be changed, waived, discharged, or terminated except by a written instrument executed by Guarantor and the Bank. -14- Section 6.06. FURTHER ASSURANCES. GUARANTOR hereby agrees to execute and deliver all such instruments and take all such action as the Bank may from time to time reasonably request in order fully to effectuate the purposes of this Guaranty. Section 6.07. EFFECTIVENESS OF THE GUARANTY. Any provision of this Guaranty which is prohibited or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof, and any such prohibition or unenforceability in any jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction. Section 6.08. SURVIVAL OF REPRESENTATIONS AND WARRANTIES; ENTIRE AGREEMENT. All representations, warranties, and covenants made by Guarantor herein or made in writing by or on behalf of Guarantor in connection herewith shall survive the execution and delivery of this Guaranty, the transfer by the Bank of the Operative Documents, or portion thereof or interest therein and the payment and performance of the Guaranteed Obligations, and may be relied upon by any assignee of the Bank, regardless of any investigation made at any time by or on behalf of the Bank or any assignee of the Bank. Subject to the preceding sentence, this Guaranty embodies the entire agreement and understanding between the Bank and the undersigned and supersedes all prior agreements and understandings relating to the subject matter hereof. Section 6.09. GOVERNING LAW. THIS GUARANTY SHALL BE CONSTRUED AND ENFORCED IN ACCORDANCE WITH AND GOVERNED BY THE LAWS OF THE STATE OF NEW YORK. Section 6.10. RIGHT OF SET-OFF. Upon the occurrence of and during the continuance of an Event of Default, the Bank is hereby authorized at any time and from time to time to the fullest extent permitted by law, to set-off and apply against any and all obligations of Guarantor now or hereafter existing under this Guaranty, (i) any and all balances in every deposit account of Guarantor with the Bank now or at any time hereafter existing, (ii) any and all other rights or claims of Guarantor against the Bank and (iii) any and all money, instruments, securities, documents, chattel paper, or other property or rights of Guarantor which may now or at any time hereafter be in possession or custody or under control of the Bank or any office or agency of the Bank, and the proceeds, products and accessions of and to any thereof. The Bank agrees to promptly notify Guarantor after any such set-off and application made by the Bank, PROVIDED that the failure to give such notice shall not affect the validity of such set-off and application. Section 6.11. MISCELLANEOUS. Guarantor agrees that all payments to be made by it hereunder shall be made to the Bank without set-off or counterclaim in lawful currency of the United States of America in immediately available funds through the New York Federal Reserve Bank to the branch of the Bank located at 12 East 49th Street, New York, N.Y. 10017, in United States Dollars. -15- IN WITNESS WHEREOF, the undersigned has duly executed and delivered this Guaranty on the day and year first above written. ENRON OIL & GAS COMPANY By: Name: Ben B. Boyd Title: Vice President and Controller -16- EX-22 20 SUBSIDIARIES EXHIBIT 22 ENRON OIL & GAS COMPANY AND SUBSIDIARIES Date of Where Company Name Incorporation Incorporated Enron Oil & Gas Company 6/12/85 Delaware Enron Asia-Middle East Exploration Company 1/17/85 Texas Enron Oil Egypt Ltd. 1/11/91 Cayman Islands Enron Oil Malaysia Inc. 5/6/85 Texas Enron Oil Malaysia, Limited 11/17/92 Cayman Islands Enron Exploration Company 5/27/93 Delaware Enron Exploration Company, Trinidad 6/2/93 Delaware Enron Trinidad Exploration Company 6/2/93 Cayman Islands Enron Gas & Oil Trinidad Limited 11/4/92 Trinidad Enron Exploration Company, Australia 6/2/93 Delaware Enron Australia Exploration Company 6/2/93 Cayman Islands Enron Exploration Australia Pty Ltd 11/23/92 Australia Enron Exploration Company, France 6/2/93 Delaware Enron Exploration France S.A. 11/13/92 France Enron Exploration Company, Russia 7/29/93 Delaware Enron Exploration and Production (Russia) Limited 11/9/92 Cyprus Enron Exploration Company, Kazakhstan 7/29/93 Delaware Enron Exploration and Production (Kazakhstan) Limited 2/8/93 Cyprus Enron Exploration Company, South America 8/3/93 Delaware Enron Exploration S.A. 12/12/91 Argentina Enron Exploration Company, United Kingdom 7/29/93 Delaware Galliford Projects Nederland B.V. 12/4/81 The Netherlands Enron Oil U.K. Limited 5/22/90 England Enron Oil & Gas Marketing, Inc. 4/9/90 Delaware I N Holdings, Inc. 3/13/85 Delaware Enron Oil Canada Ltd. 4/1/82 Alberta EX-23.1 21 CONSENT DEGOLYER AND MACNAUGHTON EXHIBIT 23.1 DeGolyer and MacNaughton One Energy Square Dallas, Texas 75206 March 16, 1994 Enron Oil & Gas Company 1400 Smith Street Houston, Texas 77002 Gentlemen: We hereby consent to the references to our firm and to our opinions delivered to Enron Oil & Gas Company, hereinafter referred to as the "Company," relating to our comparison of estimates prepared by us to those furnished to us by the Company of proved oil, condensate, natural gas liquids, and natural gas reserves of certain selected properties owned by the Company as expressed in our letter reports dated January 23, 1992, January 20, 1993, and January 27, 1994, for estimates as of January 1, 1992, January 1, 1993, and January 1, 1994, respectively, to be included in the section "Supplemental Information to Consolidated Financial Statements -- Oil and Gas Producing Activities" in the Company's Annual Report on Form 10-K for the year ended December 31, 1993, to be filed with the Securities and Exchange Commission on or about March 23, 1994. We also consent to the inclusion of our letter report, dated January 27, 1994, addressed to the Company as Exhibit (24.2) to the Company's Annual Report on Form 10-K for the year ended December 31, 1993, to be filed with the Securities and Exchange Commission. Additionally, we hereby consent to the incorporation by reference of such references to our firm and to our opinions included in the Company's Form 10-K in the Company's previously filed Registration Statement nos. 33-42620 and 33-48358. Very truly yours, /s/ DeGOLYER and MacNAUGHTON DeGOLYER and MacNAUGHTON EX-23.2 22 OPINION DEGOLYER AND MACNAUGHTON EXHIBIT 23.2 DeGolyer and MacNaughton One Energy Square Dallas, Texas 75206 January 27, 1994 Enron Oil & Gas Company 1400 Smith Street Houston, Texas 77002 Gentlemen: Pursuant to your request, we have prepared estimates, as of January 1, 1994, of the proved oil, condensate, natural gas liquids, and natural gas reserves of certain selected properties in the United States and Canada owned by Enron Oil & Gas Company, hereinafter referred to as "Enron." The properties consist of working interests located in the states of New Mexico, Texas, Utah, and Wyoming and in the offshore waters of Texas in the United States and in the province of Saskatchewan in Canada. Our estimates are reported in detail in our "Report as of January 1, 1994 on Proved Reserves of Certain Properties in the United States owned by Enron Oil & Gas company. Selected Properties" and our "Report as of January 1, 1994 on Proved Reserves of Certain Properties in Canada owned by Enron Oil & Gas Company ... Selected Properties." We also have reviewed data provided to us by Enron that it represents to be Enron's estimates of the reserves, as of January 1, 1994, for the same properties as those included in our aforementioned reports. Proved reserves estimated by us and referred to herein are judged to be economically producible in future years from known reservoirs under existing economic and operating conditions and assuming continuation of current regulatory practices using conventional production methods and equipment. Proved reserves are defined as those that have been proved to a high degree of certainty by reason of actual completion, successful testing, or in certain cases by adequate core analyses and electrical-log interpretation when the producing characteristics of the formation are known from nearby fields. These reserves are defined aerially by reasonable geological interpretation of structure and known continuity of oil- or gas-saturated material. This definition is in agreement with the definition of proved reserves prescribed by the Securities and Exchange Commission. Enron represents that its estimates of the proved reserves, as of January 1, 1994, net to its leasehold interests in the properties included in our report are as follows: Oil, Condensate, and Natural Gas Liquids Natural Gas Net Equivalent (thousand barrels) (million cubic feet) Million Cubic Feet 6,737 1,216,700 1,257,122 Note: Net equivalent million cubic feet is based on 1 barrel of oil, condensate, or natural gas liquids being equivalent to 6,000 cubic feet of gas. Enron has advised us, and we have assumed, that its estimates of proved oil, condensate, natural gas liquids, and natural gas reserves are in accordance with the rules and regulations of the Securities and Exchange Commission. Proved reserves estimated by us for the properties included in our reports, as of January 1, 1994, are as follows: Oil, Condensate, and Natural Gas Liquids Natural Gas Net Equivalent (thousand barrels) (million cubic feet) Million Cubic Feet 6,533 1,191,431 1,230,629 Note: Net equivalent million cubic feet is based on 1 barrel of oil, condensate, or natural gas liquids being equivalent to 6,000 cubic feet of gas. In making a comparison of the detailed estimates prepared by us and by Enron of the properties involved, we have found differences, both positive and negative, in reserve estimates for individual fields. These differences appear to be compensating to a great extent when considering the reserves of Enron in the properties included in our reports, resulting in overall differences not being substantial. It is our opinion that the reserve estimates prepared by Enron on the properties reviewed by us and referred to above, when compared on a net-equivalent-cubic-feet-of-gas basis, do not differ from those prepared by us. Submitted, /s/ DeGOLYER and MacNAUGHTON DeGOLYER and MacNAUGHTON /s/ W. G. McGilvray W. G. McGilvray, P.E. Senior Vice President DeGolyer and MacNaughton EX-24 23 POWERS OF ATTORNEY EXHIBIT 24 POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that in connection with the filing by Enron Oil & Gas Company, a Delaware corporation (the "Company"), of its Annual Report on Form 10-K for the year ended December 31, 1993 with the Securities and Exchange Commission, the undersigned officer or director of the Company hereby constitutes and appoints Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis and each of them (with full power to each of them to act alone), his true and lawful attorney-in-fact and agent, for him and on his behalf and in his name, place and stead, in any and all capacities, to sign, execute and file such Annual Report on Form 10-K together with any amendments or supplements thereto, with all exhibits and any and all documents required to be filed with respect thereto with any regulatory authority, granting unto said attorneys, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises in order to effectuate the same as fully to all intents and purposes as the undersigned might or could do if personally present, hereby ratifying and confirming all the said attorneys-in-fact and agents, or any of them, may lawfully do or cause to be done by virtue hereof. IN WITNESS WHEREOF, the undersigned has hereto set his hand this 8th day of February, 1994. /s/ FRED C. ACKMAN Fred C. Ackman POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that in connection with the filing by Enron Oil & Gas Company, a Delaware corporation (the "Company"), of its Annual Report on Form 10-K for the year ended December 31, 1993 with the Securities and Exchange Commission, the undersigned officer or director of the Company hereby constitutes and appoints Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis and each of them (with full power to each of them to act alone), his true and lawful attorney-in-fact and agent, for him and on his behalf and in his name, place and stead, in any and all capacities, to sign, execute and file such Annual Report on Form 10-K together with any amendments or supplements thereto, with all exhibits and any and all documents required to be filed with respect thereto with any regulatory authority, granting unto said attorneys, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises in order to effectuate the same as fully to all intents and purposes as the undersigned might or could do if personally present, hereby ratifying and confirming all the said attorneys-in-fact and agents, or any of them, may lawfully do or cause to be done by virtue hereof. IN WITNESS WHEREOF, the undersigned has hereto set his hand this 8th day of February, 1994. /s/ EDWARD RANDALL, III Edward Randall, III POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that in connection with the filing by Enron Oil & Gas Company, a Delaware corporation (the "Company"), of its Annual Report on Form 10-K for the year ended December 31, 1993 with the Securities and Exchange Commission, the undersigned officer or director of the Company hereby constitutes and appoints Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis and each of them (with full power to each of them to act alone), his true and lawful attorney-in-fact and agent, for him and on his behalf and in his name, place and stead, in any and all capacities, to sign, execute and file such Annual Report on Form 10-K together with any amendments or supplements thereto, with all exhibits and any and all documents required to be filed with respect thereto with any regulatory authority, granting unto said attorneys, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises in order to effectuate the same as fully to all intents and purposes as the undersigned might or could do if personally present, hereby ratifying and confirming all the said attorneys-in-fact and agents, or any of them, may lawfully do or cause to be done by virtue hereof. IN WITNESS WHEREOF, the undersigned has hereto set his hand this 8th day of February, 1994. /s/ KENNETH L. LAY Kenneth L. Lay POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that in connection with the filing by Enron Oil & Gas Company, a Delaware corporation (the "Company"), of its Annual Report on Form 10-K for the year ended December 31, 1993 with the Securities and Exchange Commission, the undersigned officer or director of the Company hereby constitutes and appoints Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis and each of them (with full power to each of them to act alone), his true and lawful attorney-in-fact and agent, for him and on his behalf and in his name, place and stead, in any and all capacities, to sign, execute and file such Annual Report on Form 10-K together with any amendments or supplements thereto, with all exhibits and any and all documents required to be filed with respect thereto with any regulatory authority, granting unto said attorneys, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises in order to effectuate the same as fully to all intents and purposes as the undersigned might or could do if personally present, hereby ratifying and confirming all the said attorneys-in-fact and agents, or any of them, may lawfully do or cause to be done by virtue hereof. IN WITNESS WHEREOF, the undersigned has hereto set his hand this 8th day of February, 1994. /s/ RICHARD D. KINDER Richard D. Kinder -----END PRIVACY-ENHANCED MESSAGE-----