0001144204-14-007620.txt : 20140211 0001144204-14-007620.hdr.sgml : 20140211 20140211163035 ACCESSION NUMBER: 0001144204-14-007620 CONFORMED SUBMISSION TYPE: 8-K/A PUBLIC DOCUMENT COUNT: 51 CONFORMED PERIOD OF REPORT: 20130925 ITEM INFORMATION: Completion of Acquisition or Disposition of Assets ITEM INFORMATION: Unregistered Sales of Equity Securities ITEM INFORMATION: Departure of Directors or Certain Officers; Election of Directors; Appointment of Certain Officers: Compensatory Arrangements of Certain Officers ITEM INFORMATION: Change in Shell Company Status ITEM INFORMATION: Financial Statements and Exhibits FILED AS OF DATE: 20140211 DATE AS OF CHANGE: 20140211 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Woodgate Energy Corp CENTRAL INDEX KEY: 0001558902 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 000000000 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 8-K/A SEC ACT: 1934 Act SEC FILE NUMBER: 000-54834 FILM NUMBER: 14594674 BUSINESS ADDRESS: STREET 1: 2500 TANGLEWILDE STREET 2: SUITE 260 CITY: HOUSTON STATE: TX ZIP: 77063 BUSINESS PHONE: 713-978-6551 MAIL ADDRESS: STREET 1: 2500 TANGLEWILDE STREET 2: SUITE 260 CITY: HOUSTON STATE: TX ZIP: 77063 FORMER COMPANY: FORMER CONFORMED NAME: Woodgate Acquisition Corp DATE OF NAME CHANGE: 20120924 8-K/A 1 v367661_8ka.htm 8-K/A

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K/A

Amendment No. 2

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

September 25, 2013

Date of Report

(Date of Earliest Event Reported)

WOODGATE ENERGY CORPORATION

(Exact Name of Registrant as Specified in its Charter)

Delaware	000-54834	46-1874004
(State or other jurisdiction	(Commission File Number)	(IRS Employer
of incorporation)		Identification No.)

2500 Tanglewilde

Suite 260

Houston, TX 77063

(Address of Principal Executive Offices)

(713) 978-6551

(Registrant’s Telephone Number)

ITEM 2.01

Completion of Acquisition or Disposition of Assets

On September 25, 2013, WoodGate Energy Corporation, a Delaware corporation (the “Company”), completed the acquisitions of two entities in separate stock-for stock transactions (collectively, and together, the “Acquisitions): (1) E&P CO, LLC, a Texas limited liability company (“EPCO”) and (2) Prestige O&G, LLC, a Texas limited liability company (“Prestige”). The purpose of the Acquisitions was to facilitate and prepare the Company for a registration statement and/or public offering of securities. The acquisition by the Company of EPCO is referred to herein as the “EPCO Acquisition,” and the acquisition by the Company of Prestige is referred to herein as the “Prestige Acquisition.”

The EPCO Acquisition was effectuated by the Company through the exchange of each of the outstanding membership units of EPCO for 10,000 shares of common stock of the Company. As a result, in the EPCO Acquisition, all of the outstanding membership interests in aggregate of EPCO were exchanged for, and converted into, 13,337,280 shares of common stock of the Company. In addition, as part of the EPCO Acquisition, EPCO’s outstanding debt was converted into shares of common stock of the Company, resulting in 13,296,950 shares of common stock of the Company being issued to holders of EPCO’s debt. Hence, the Company issued a total of 26,634,230 shares of common stock of the Company in the EPCO Acquisition.

The Prestige Acquisition was effectuated by the Company through the exchange of each of the outstanding membership units of Prestige for 10,000 shares of common stock of the Company. As a result, in the Prestige Acquisition, all of the outstanding membership interests in aggregate of Prestige were exchanged for, and converted into, 10,115,770 shares of common stock of the Company.

In sum, a total of 36,750,000 shares of common stock of the Company were issued in the Acquisitions.

EPCO was formed in June 2005 in the State of Texas, and is engaged in the development, drilling and production of coal bed methane (CBM) gas on a concession located in the State of Louisiana. EPCO is engaged in the exploration and development of CBM wells, and it currently holds three producing wells and one salt water disposal well, and is in the process of developing additional wells. The main source of revenue for the Company is sale of CBM gas to Regency Gas Services, LLC. EPCO currently has access to about 10,000 net mineral acres of land (through a lease) which has the potential of developing additional CBM wells.

Prestige was formed in June 2009 in the State of Texas, and invests in and develops oil and gas exploration and production projects mainly in the United States . As one of its major investments, Prestige formerly held an interest in EPCO (which interest was withdrawn on June 30, 2013 in preparation for the Acquisitions) and is currently a partner with EPCO in its CBM Gas Project in the State of Louisiana.

As a result of the Acquisitions, each of EPCO and Prestige became wholly owned subsidiaries of the Company. The Company, as the sole shareholder of each of EPCO and Prestige, has taken over the operations and business plans of each of EPCO and Prestige.

General

The Company’s common stock is not currently trading on any public markets in the United States.

As of the date of this report (September 25, 2013), the Company had approximately 35 holder of its common stock.

The Company has not declared any dividends in its fiscal years ended December 31, 2012 or December 31, 2011, respectively. Similarly, the Company did not declare any dividends during the six months ended June 30, 2013. Currently, the Company has no intention of paying cash dividends in the foreseeable future, but rather intends to use any future earnings for the development of its business in the foreseeable future.

Capitalization

The Company is authorized to issue 100,000,000 shares of common stock, par value $0.0001, of which 47,295,000 shares are outstanding as of the date of this report. The Company is also authorized to issue 20,000,000 shares of preferred stock, par value $0.0001, of which no shares were outstanding as of the date of this report.

The following statements relating to the capital stock set forth the material terms of the securities of the Company, however, reference is made to the more detailed provisions of, and such statements are qualified in their entirety by reference to, the certificate of incorporation and the by-laws.

Common Stock

Holders of shares of common stock are entitled to one vote for each share on all matters to be voted on by the stockholders. Holders of common stock do not have cumulative voting rights.

Subject to preferences that may be applicable to any outstanding shares of preferred stock, the holders of common stock are entitled to share ratably in dividends, if any, as may be declared from time to time by the board of directors in its discretion from funds legally available therefor.

Holders of common stock have no preemptive rights to purchase the Company’s common stock. There are no conversion or redemption rights or sinking fund provisions with respect to the common stock. The Company may issue additional shares of common stock which could dilute its current shareholder's share value.

Preferred Stock

Shares of preferred stock may be issued from time to time in one or more series as may be determined by the board of directors. The board of directors may fix the designation, powers, preferences and rights of the shares of each such series and the qualifications, limitations or restrictions thereof without any further vote or action by the stockholders of the Company, except that no holder of preferred stock shall have preemptive rights. Any shares of preferred stock so issued would typically have priority over the common stock with respect to dividend or liquidation rights. The board of directors does not at present intend to seek stockholder approval prior to any issuance of currently authorized stock, unless otherwise required by law or otherwise.

Relationship with Tiber Creek Corporation

In March 2013 the Company entered into an engagement agreement with Tiber Creek Corporation, a Delaware corporation (“Tiber Creek”), whereby Tiber Creek would provide assistance to the Company in effecting transactions for the Company to combine with a public reporting company, including: transferring control of such reporting company to the Company; preparing the business combination agreement; effecting the business combination; causing the preparation and filing of forms, including a registration statement, with the Securities and Exchange Commission; assist in listing its securities on a trading exchange; and assist in establishing and maintaining relationships with market makers and broker-dealers.

Under the agreement, Tiber Creek is entitled to receive cash fees from the Company. In addition, the Company’s then-current shareholders, Tiber Creek and MB Americus, LLC, a California limited liability company (“MB Americus”), were permitted to retain the aggregate total of 500,000 shares.

In general, Tiber Creek holds interests in inactive Delaware corporations which may be used by issuers (such as the Company) to reincorporate their business in the State of Delaware and capitalize the issuer at a level and in a manner (i.e. the number of authorized shares and rights and preferences of shareholders) that is appropriate for a public company. Otherwise, these corporations, such as Silverwood Acquisition Corporation (the former name of the Company), are inactive, and Tiber Creek does not conduct any business in such corporations.

James Cassidy and James McKillop (who is the sole owner of MB Americus, an affiliate of Tiber Creek) serve only as interim officers and directors of these corporations (such as Woodgate Acquisition Corporation) until such time as the changes of control in such corporations are effectuated to the ultimate registering issuers. As the role of Tiber Creek is essentially limited to preparing the corporate structure and organizing the Company for becoming a public company, the roles of Mr. Cassidy and Mr. McKillop are generally limited to facilitating such change of control and securities registration transactions.

Business

Prior to the Acquisition, the Company had no significant business, operations or plan. Accordingly, the business of the Company below is that of EPCO and Prestige, each of which the Company acquired in the Acquisitions.

The Company is specialized in the field of operating and managing natural gas projects.

EPCO commenced developing wells and raising funds to finance well development activities and initiated the process of drilling the third gas production well during 2010 and completed lateral drilling of the third well in 2011. Through its efforts to date, EPCO has a complete, fully operational processing facility and three developed and producing wells with limited quantities of gas pending the stabilization of the wells, in addition to one saltwater disposal well. The gas process facility is designed to accommodate approximately 30 wells and includes a main connection to the sales pipeline network.

EPCO (with which Prestige is a partner) is the primary owner company of NE Caldwell Gas project in Louisiana. EPCO has completed the development of the first three wells from its own resources where existing wells are operational and producing natural gas. EPCO has successfully conducted directional drilling techniques in its operation where lateral drilling was successfully completed so far. All current production is being sold under an agreement with Regency Gas Services, LLC.

Prestige O & G, LLC invests in and develops oil and gas projects in the United States. Prestige, since its inception in 2009, held an interest in EPCO (which interest was withdrawn on June 30, 2013 in preparation for the Acquisitions) and is currently a partner with EPCO in its CBM Gas Project NE Caldwell in the State of Louisiana. In June 2013, EPCO entered into a participation agreement with Prestige to establish a partnership in this project whereby each of EPCO and Prestige now holds a 50% interest in the project. Prestige also holds interest in another project (Washington project) which is in very initial stage.

The Company holds a significant competitive position in CBM industry in this area. The company is developing a basin with only minimal activity by the competitors. The Company has a 9,661-acre lease from a single mineral owner. The Company is now the only operator selling into the sales trunk pipeline owned by Regency Marketing.

The Company benefits from geologic and reservoir knowledge acquired by its operations as wells as data packages included for nearby projects as other operators have exited the area, allowing the company to optimize future operations.

Coal Bed Methane (CBM) Resources

The Company’s business is centered on coal bed methane energy.

CBM gas is a clean source of energy in the form of CH4 composite (methane natural gas). CBM is produced under unconventional means from coal seams. The Company’s management believes that interest in developing CBM projects is increasing in recent years by public and private sectors; accordingly CBM operations and businesses are expected to continue to grow in the future driven by CBM’s importance as an energy source and anticipated to increase in demand for natural gas as a growing source of energy.

In 2011, the Company (through EPCO) engaged Netherland, Sewell & Associates, Inc. (“Netherland Sewell”), worldwide petroleum consultants and specialists in engineering, geology, geophysics and petrophysics, to assess the gross contingent and prospective resources for certain coal bed methane properties located in Caldwell Parish, Louisiana (the area assessed represented only a portion of the acreage in which EPCO holds an interest). The assessment made was prepared in accordance with the definitions and guidelines set forth in the 2007 Petroleum Resources Management System (PRMS) approved by the Society of Petroleum Engineers (SPE).

Netherland Sewell assessed the contingent gas resources, which are those quantities of petroleum which are estimated to be potentially recoverable from known accumulations, but for which the applied project(s) are not yet considered mature enough for commercial development because of one or more contingencies. The contingent resources assessed are considered contingent upon increasing the individual gas production rates for existing wells to sufficiently demonstrate the commerciality of the project(s).

In addition to the Netherland Sewell analysis, the Company has also confirmed these assessments through analysis by Supreme Source Energy Services (SSES, a CBM engineering and drilling specialist firm, and Intertek Westport Technology Center, a consultant and laboratory analyst to the oil and gas exploration and production industry.

Strategic Partners and Suppliers

The Company believes that strategic partnerships will be a major component of the Company’s operating strategy and path to success. The Company plans to work with several strategic partners in important areas of its business and operations to promote its development activities in efforts to maintain the competitive edge in the CBM industry.

Customer Agreement

The main source of revenue for the Company (through EPCO) is the sale of CBM gas to Regency Gas Services, LLC (together with all of its affiliates, collectively, “Regency”) through various off-take agreements to sell all produced gas at prevailing market prices. Pursuant to the agreement, which includes Regency Intrastate Gas LP, a tap, valve and metering facility for the receipt of gas by Regency from EPCO was set up by the parties. Pursuant to the agreement, the Company will receive revenues upon sales of gas each month.

EPCO Lease from International Paper Company

On May 1, 2008, EPCO entered into an exploration agreement with coal bed methane lease option east with International Paper Company (“International Paper Agreement”). Under the International Paper Agreement, EPCO has rights to explore for, and otherwise evaluate, deposits of coal containing coal bed methane in certain areas in Caldwell Parish, Louisiana comprising approximately 9,661 acres. Pursuant to the International Paper Agreement, EPCO exercised a lease option in 2008 allowing it to proceed with development and production projects in this area. Since then, EPCO has annually renewed such lease for its project development (the current period, as recently renewed, runs to April 30, 2014) for and in consideration of the negotiated sum of $19,322 and other good and valuable consideration by the Lessor. The current annual renewal extending the primary term of the coal bed methane lease until April 30, 2014 covers all of the 9,661 acres under the original lease. Further annual extensions will also require the Company to pay default penalty at a rate of $2 per acre.

Further, in June 2013, EPCO entered into a participation agreement with Prestige to establish a partnership in this project whereby each of EPCO and Prestige now hold a 50% interest in the project. The International Paper Agreement is being managed for International Paper Company by BRP, LLC, a joint venture owned by International Paper Company and Natural Resource Partners L.P., a publicly traded master limited partnership. Currently, the Company pays approximately $2.00 per acre for the lease each year in addition to the royalty payments upon sales of gas each month. The royalty is determined based on base royalty rate of 12.5% plus a supplemental royalty based on the gross sales price of the CBM.

Governmental Regulations

The Company holds various licenses and permits to drill, operate and conduct such exploration activities in Louisiana. Based on the nature of operations, the Company has only a set of established regulations for compliance. There are no material public or State objections to oil & gas development in Louisiana.

The Company does not need or require any other approval from government authorities or agencies in order to operate its regular business and operations. However, it is possible that any proposed expansion to the Company’s business and operations in the future would require government approvals.

Marketing and Sales

Due to the secured off take agreement with Regency for the sale of all Gas production of the Company, The Company has conducted limited advertising and marketing to date.

The Company, however, is planning to construct a marketing plan which aims to maintain a competitive edge in the CBM market and to promote the company as a poineer player in this industry.

Revenues and Losses

The Company has limited revenues from operations. Based solely on combining EPCO and Prestige, the Company would have been deemed to have revenues of $399,131 during the year ending 2011, ($263,204) in the year ended 2012 and ($269,176) for the first half of 2013.

The Company has a record of posting losses. Based solely on combining EPCO and Prestige, the Company would have been deemed to have net losses of $646,916 during the year ending 2011, $591,459 in the year ended 2012 and $880,767 for the first half of 2013.

THE COMPANY

Employees and Organization

The Company presently (with its subsidiaries) has four employees in its payroll. The Company also regularly engages contractors and sub-contracts to directly work in the wells in Louisiana.

The employees receive health insurance benefits. The Company may offer additional fringe and welfare benefits in the future as the Company’s profits grow and/or the Company secures additional outside financing or its profits from operations allow expenditure on such items.

Stephen Spafford, an operational manager, has an employment agreement with EPCO, entered into as of May 2010. Pursuant to this agreement, Mr. Spafford is entitled to a base salary of $200,000, plus eligibility for performance bonuses and other perquisites. The employment agreement with Mr. Spafford has a term of one year, and is subject to annual renewals by mutual consent.

Samta Gupta, an accountant, has an employment agreement with EPCO, entered into as of June 2009. Pursuant to this agreement and further revisions, Ms. Gupta is currently entitled to a salary of $65,000, plus eligibility for certain perquisites.

Property

The Company’s headquarters are located in Houston, Texas. The office location leased from Woodlake Properties consists of approximately 3,000 square feet. The monthly lease cost for the Company is $3,927 at present.

The Company leases the land (almost 10,000 acres) on which its wells are located in Columbia, Louisiana. The total land area can accommodate up to 150 to 200 wells.

Subsidiaries

Currently, the Company has two subsidiaries – EPCO and Prestige (each of which was acquired in the Acquisitions). The Company is the sole owner/member of each of EPCO and Prestige.

Intellectual Property

The Company holds limited intellectual property, and has not applied for any patents. The Company does hold one trademark issued by the U.S. Patent and Trademark Office for “E & Pco, LLC EXPLORATION AND PRODUCTION.” The trademark was registered in March 2012 and covers Class 37 for oil and gas development and related activities.

Summary Financial Information

As the Company had no operations or specific business plan until the Acquisitions, the information presented below is with respect to EPCO and Prestige, respectively, which were each acquired by the Company in September 2013 as a result of the Acquisitions.

The statements of operations data for the six months ended June 30, 2013 and the balance sheet data as of June 30, 2013 are derived from the audited financial statements of EPCO and related notes thereto included herewith (the audit was conducted with respect to the financial statements of EPCO in conformity with accounting principles generally accepted in the United States). The statement of operations data for the year ended December 31, 2012 and the year ended December 31, 2011, respectively, and the balance sheet data as of December 31, 2012 and December 31, 2011, respectively, provided below, is derived from the audited financial statements of EPCO and related notes thereto included herewith (the audit was conducted with respect to the financial statements of EPCO in conformity with accounting principles generally accepted in the United States).

	Six months ended			Year ended			Year ended
	June 30, 2013			December 31, 2012			December 31, 2011
Statement of operations data
Revenue	$	2,141		$	4,420		$	13,046
Gross profit	$	2,141		$	4,420		$	13,046
Income (Loss) from operations	$	(763,026	)	$	(862,003	)	$	(724,205	)
Net income (loss)	$	(763,026	))	$	(620,477	)	$	(683,055	)

	At June 30, 2013			At December 31, 2012			At December 31, 2011
Balance sheet data
Cash	$	34,900		$	47,762		$	(93,821	)
Other assets	$	17,321,203		$	19,097,721		$	19,103,756
Total assets	$	17,356,103		$	19,145,483		$	19,197,577
Total liabilities	$	10,496,454		$	14,477,401		$	15,424,018
Total members’ equity (deficit)	$	6,859,649		$	4,668,082		$	3,773,559

The statements of operations data for the six months ended June 30, 2013 and the balance sheet data as of June 30, 2013 are derived from the audited financial statements of Prestige and related notes thereto included herewith (the audit was conducted with respect to the financial statements of Prestige in conformity with accounting principles generally accepted in the United States). The statement of operations data for the year ended December 31, 2012 and the year ended December 31, 2011, respectively, and the balance sheet data as of December 31, 2012 and December 31, 2011, respectively, provided below, is derived from the audited financial statements of Prestige and related notes thereto included herewith (the audit was conducted with respect to the financial statements of Prestige in conformity with accounting principles generally accepted in the United States).

	Six months ended			Year ended			Year ended
	June 30, 2013			December 31, 2012			December 31, 2011
Statement of operations data
Revenue	$	(271,317	)	$	(267,624	)	$	386,085
Gross profit	$	(271,317	)	$	(267,624	)	$	386,085
Income (Loss) from operations	$	(117,741	)	$	29,018		$	(21,551	)
Net income (loss)	$	(117,741	)	$	29,018		$	36,139

	At June 30, 2013			At December 31, 2012			At December 31, 2011
Balance sheet data
Cash	$	5,338		$	5,338		$	5,338
Other assets	$	10,049,517		$	9,908,442		$	9,858,490
Total assets	$	10,054,855		$	9,913,780		$	9,863,828
Total liabilities	$	0		$	195,626		$	174,692
Total members’ equity (deficit)	$	10,054,855		$	9,718,155		$	9,689,136

Management's Discussion and Analysis of Financial Condition and Results of Operations

References to the financial condition and performance of the Company below in this section “Management’s Discussions and Analysis of Financial Condition and Results of Operation” are to EPCO and Prestige (as the Company did not have business operations of a material nature prior to the consummation of the Acquisitions).

Revenues and Losses

Equipment Financing

The Company has no existing equipment financing arrangements.

Potential Revenue

The Company expects to earn potential revenue from arrangement with Regency. As the Company expands its gas-producing capacity through expansion of its wells in Louisiana, the Company plans to achieve additional revenue.

Alternative Financial Planning

The Company has no alternative financial plans at the moment. If the Company is not able to generate increased revenues and profits and/or successfully raise monies as needed through a private placement or other securities offering (including, but not limited to, a primary public offering of securities), the Company’s ability to expand its business plan or strategy over the next two years will be jeopardized.

Critical Accounting Policies

For the years ending December 31, 2012 and December 31, 2011, respectively, the financial statements of EPCO and Prestige have been prepared and audited in accordance with generally accepted accounting principles in the United States. For the six months ended June 2013, the financial statements of EPCO and Prestige were audited in accordance with generally accepted accounting principles in the United States (preparation of the financial statements for Prestige and EPCO was made under generally accepted accounting principles in the United States (GAAP)).

The financial statements have been prepared under historical cost convention. The preparation of financial statements in conformity with GAAP requires the use of certain critical accounting estimates and management of the Company to exercise its judgment in the process of applying accounting principles. Estimates and judgments are continually evaluated and are based on historical experience and other factors, including expectations of future events that are believed to be reasonable under the circumstances. The Company makes estimates and assumptions concerning the future.

Capital Resources

As of June 30, 2013, the Company (based on a combination of EPCO and Prestige) had cash available of $40,238.

The Company’s proposed business plans over the next two years will necessitate additional capital and financing. Accordingly, the Company plans to raise some outside funding in the next one year, for the purposes of funding its business development and expansion plans. The company expects no material capital expenditure in 2014 apart from supporting the subsidiary companies to complete the development of the existing 3 wells in addition to drill one or two new wells.

There can be no assurance that the Company’s activities will generate sufficient revenues to sustain its operations without additional capital, or if additional capital is needed, that such funds, if available, will be obtainable on terms satisfactory to the Company. Accordingly, given the Company’s limited cash and cash equivalents on hand, the Company will be unable to implement its contemplated business plans and operations unless it obtains additional financing or otherwise is able to generate sufficient revenues and profits. The Company may raise additional capital through sales of debt or equity, obtain loan financing or develop and consummate other alternative financial plans.

To date, the Company has not suffered from a significant liquidity issue. However, the Company has been able to avoid such liquidity issues because of a revolving funding arrangement that it has in place with affiliated entities, Rasan Associates, LLC and Rasan Private Equity, Inc. (collectively, “Rasan”). Under this arrangement, the Company receives funding from a commodity sale and purchase agreement with Rasan. The Company received funding from Rasan Private Equity at 7% p.a. and the short term financing were renewed for another similar period upon expiration of the original term. Rasan Associates, LLC provided interest free short term funding. Most of these loans were converted into equity upon acquisition of EPCO and Prestige by the Company.

Discussion of Six Months ended June 30, 2013

Based on a combination of EPCO and Prestige the Company generated no revenues during the six months ended June 30, 2013. The Company posted net losses of $880,767 for the six months ended June 30, 2013. The expenses incurred and losses consisted primarily of funds expended to further the Company’s business and operational activities.

Discussion of the Year ended December 31, 2012

Based on a combination of EPCO and Prestige the Company generated revenues of ($263,204) during the year ended December 31, 2012. The Company posted net losses of $591,459 for the year ended December 31, 2012. The expenses incurred and losses consisted primarily of funds expended to further the Company’s business and operational activities.

Discussion of the Year ended December 31, 2011

Based on a combination of EPCO and Prestige the Company generated revenues of $399,131 during the year ended December 31, 2012. The Company posted net losses of $646,916 for the year ended December 31, 2012. The expenses incurred and losses consisted primarily of funds expended to further the Company’s business and operational activities.

Management

The following table sets forth information regarding the members of the Company’s board of directors and its officers:

Name	Age	Position	Year Commenced

Fuad Al-Humoud	50	President and Director	2013
Osman Kaldirim, Jr.	34	Director	2013
Dr. Osman Kaldirim	61	Vice-Chairman and Director	2013
Mel Bernstein	42	Director	2013

Fuad Al-Humoud

Fuad Al-Humoud serves as the President, Chairman of the Board of Directors of the Company, and is a director of the Company. Mr. Al-Humoud has 22 years of experience in banking, investments and real estate fields with particular emphasis on financial engineering, investment development (private equity, funds and direct investment), Treasury operations, portfolio management and leasing and project financing. Mr. Al-Humoud has extensive entrepreneur experience in activities related to business development and financial structuring for start-up as well as existing investment programs. Mr. Al-Humoud has over 15 years experience in establishing financial institutions in banking, finance, and the investment sector contributing to development of the business plan, and operational, investment and business policies. Mr. Al-Humoud continues to hold executive positions in Rasan Associates, LLC and Rasan Energy Company. He also holds the position of Chairman for Rasan Holding. He devotes about 60% of his time for the Company. Mr. Al-Humoud received his Bachelor of Science in Industrial Engineering degree in 1988 from The University of Miami.

Osman Kaldirim, Jr.

Osman Kaldirim, Jr. serves as a director of the Company. Mr. Kaldirim is a Petroleum Geologist with a broad background in prospect generation and prospect evaluation together with various operating management functions in oil and gas projects, including both U.S. and International projects. Mr. Kaldirim has over nine years experience in the Oil & Gas sector with main focus on Exploration & Development of unconventional Oil & Gas Projects using conventional and non-conventional drilling techniques, production planning and project management. Since 2005 to the present, Mr. Kaldirim has served as the Vice President and Chief Geologist at E&P Co., LLC and has been managing the drilling, exploration and development of multiple wells in their 10,000 acres, Northeast Caldwell CBM Project in Louisiana. Mr. Kaldirim received Masters Degree in Petroleum/Structural Geology in 2004 from Oklahoma State University and his Bachelor of Science Degree in Geology from Texas A&M University in 2002. Mr Kaldirim is the son of Dr. Osman Kaldirim, one of the directors of the Company.

Dr. Osman Kaldirim

Dr. Osman Kaldirim serves as the Vice-Chairman and a director of the Company and Chairman of E&P Co., Dr. Kaldirim is currently the CEO and President of Delta Oil Company and also the president of Delta Oil Central Asia Company. He is experienced in new project developments, negotiation and implementation of several on-shore and off-shore po; and gas projects. He was also a member of a team for UNOCAL Company for new project development and contracts negotiation in the Central Asia. His work in Azerbaijan contributed towards the negotiation of the first production-sharing contract (PSC) for the Caspian Sea oil field development. The contract intends that over $13 billion US Dollars are to be invested by twelve major oil companies from seven different countries.

Dr. Kaldirim has also made an important contribution to oil and gas pipeline projects in Central Asia including Baku- Tiflis- Ceyhan Oil pipeline. Dr. Kaldirim became chairman of the gas pipeline project development (from Turkmenistan to Pakistan) named CentGas Company. This project, currently on hold pending resolution of Afghanistan issues, requires an investment of approximately $4 billion US Dollars. Dr. Kaldirim is one of the founders of one the major oil pipeline project named CentOil pipeline Company (from Kazakistan, Uzbakistan, Turkmensitan, to Arabian Sea port in Pakistan) expected to establish pipelines that will open a market to these Central Asian countries for their products and will create additional alternative sources for oil and gas for the rest of the world. He has been involved in providing his consulting, contracting and representation services to engineering and construction and energy related companies for development and infrastructure projects in Central Asia and Middle East.

Dr. Kaldirim has also been involved in many other types of projects such as the development of the first Arabic/English microcomputers (he was a founder and developer of Research Computer Technology Company in California (RCTC)). He was one of the developers and founders of American Fiber Optic Company in Long Beach California. Dr. Kaldirim played a major role in the development of the high frequency low noise analog optical receiver and transmitter system for the U.S. defense department. He has worked as senior scientist, advisor and consultant for many international companies and countries including the United States at the highest levels.

Dr. Kaldirim has more than 30 classified publications and scientific articles related to electronics, EMP, EMI, Fiber optic and integrated optics. He also holds patents in Biomedical Engineering, specifically, micro-spherical protein movement using electromagnetic force in the body. Dr. Kaldirim also has an associate professorship, awarded by the ministry of higher education in Turkey.

Dr. Kaldirim received his Bachelor’s degree in Electrical Engineering from Yildiz University in Istanbul in 1975 followed by his Master's Degree (MSc) in 1977, Engineering Degree (ED) in 1979, Ph.D. in 1981 and studied towards MBA in 1982 from the University of California Los Angeles (UCLA). He holds both US and Turkish citizenship. Dr. Kaldirim is the father of Osman Kaldirim, Jr., one of the directors of the Company.

Mel Bernstein

Mel Bernstein serves as a director of the Company. Mr. Bernstein has over 20 years of real estate, finance and investment experience at the executive level. Mr. Bernstein has experience in generating, implementing and managing residential and commercial real estate services in sales, leasing, exclusive representation, property management and consulting. He currently holds the position of Vice President with RE/Max Optima, a Florida based real-estate company. From 1996 to 2013 Mr. Bernstein held management executive positions with Mel Bernstein Real Estate and from 1997 to 2010 with All Florida Funding/Real Property Mortgage Investors. In addition to approximately 1800 hours of professional development in real estate education and mortgage finance education, Mr. Bernstein holds multiple real estate licenses and enjoys membership with various professional organizations. Mr. Bernstein is a highly skilled and motivated professional. He has a proven track record in managing distressed projects making positive turn around. He is highly result oriented and can handle challenging business events. His experience surely meets the qualification needed to take the Company (WGE) into the next level. His independent advice and input serving as a director is without doubt a value to the company.

Director Independence

Pursuant to Rule 4200 of The NASDAQ Stock Market one of the definitions of an independent director is a person other than an executive officer or employee of a company. The Company's board of directors has reviewed the materiality of any relationship that each of the directors has with the Company, either directly or indirectly. Based on this review, the board has one independent director – Mel Bernstein.

Committees and Terms

The Board of Directors (the “Board”) has not established any committees.

Legal Proceedings

There are currently no pending, threatened or actual legal proceedings of a material nature in which the Company is a party.

EPCO was a party to the lawsuit entitled Noram Drilling Company v. E&P Co International, LLC and E&P Co., LLC. The case has been pending in Caldwell Parish, Louisiana since originally filed in 2009. EPCO, which was a party to the suit, was dismissed following a motion for summary judgment adjudicated in its favor in 2013. Accordingly, EPCO is no longer a party to this proceeding.

Anticipated Officer and Director Remuneration

The Company pays reduced levels of compensation to certain of its officers and directors at present. The Company intends to pay regular, competitive annual salaries to all its officers and directors and will pay an annual stipend to its directors when, and if, it completes a primary public offering for the sale of securities and/or the Company reaches greater profitability, experiences larger and more sustained positive cash flow and/or obtains additional funding. At such time, the Company anticipates offering additional cash and non-cash compensation to officers and directors. In addition, the Company anticipates that its officers and directors will be provided with additional fringe benefits and perquisites at subsidizes rates, or at the sole expense of the Company, as may be determined on a case-by-case basis by the Company in its sole discretion. In addition, the Company may plan to offer 401(k) matching funds as a retirement benefit at a later time.

The Company’s Board of Directors is expected to determine the Company's (and its subsidiary companies) Officers' and Directors' remuneration in the upcoming Board meeting expected in February 2014 when the 2013 financials are reviewed. The Company has allocated a budget of $600,000 ($300,000 at Company’s level and $300,000 at EPCO’s level) for this purpose, however, the final amounts will be determined according to the aforementioned.

Certain Relationships and Related Transactions

James Cassidy, a partner in the law firm which acts as counsel to the Company, is the sole owner and director of Tiber Creek Corporation which owns 250,000 shares of the Company's common stock. Tiber Creek is entitled to receive consulting fees of $100,000 from the Company and also holds shares of common stock in the Company. Tiber Creek and its affiliate, MB Americus LLC, a California limited liability company, each currently hold 250,000 shares in the Company.

James Cassidy and James McKillop, who is the sole officer and owner of MB Americus, LLC, were both formerly officers and directors of the Company. As the organizers and developers of Moosewood, Mr. Cassidy and Mr. McKillop were involved with the Company prior to the Mergers. In particular, Mr. Cassidy provided services to the Company without charge, including preparation and filing of the charter corporate documents and preparation of the registration statement for the Company.

Mr. Fuad Al-Humoud, who is the President, Chairman and a director of the Company, was also a director of EPCO and Chairman of Prestige prior to the Acquisitions.

The Company has entered into interest free loan arrangements with its subsidiary companies EPCO and/or Prestige. EPCO has a revolving funding arrangement that it has in place with affiliated entity Rasan Private Equity, Inc. Under this arrangement, the Company receives funding from a commodity purchase and subsequent sale agreement with Rasan. Similarly, there were other funding arrangements with other affiliates of EPCO which were availed of during the last three years. Most of these loans were converted into equity upon acquisition of EPCO and Prestige by the Company.

Security Ownership of Certain Beneficial Owners and Management

The following table sets forth information as of the date of this regarding the beneficial ownership of the Company’s common stock by each of the Company’s executive officers and directors, individually and as a group and by each person who beneficially owns in excess of five percent of the common stock after giving effect to any exercise of warrants or options held by that person.

		Number of Shares of
Name	Position	Common Stock			Percent of Class (1)

Fuad Al-Humoud	Chairman, President and Director		2,384,377	(2)		5	%
8435 Chisholm Rd. Unit #9
Pensacola, Fl. 32514

Osman Kaldirim, Jr.	Director		22,515,993	(3)		48	%
6363 San Felipe Dr., Apt # 215
Houston, TX 77057

Dr. Osman Kaldirim	Vice Chairman & Director		25,540,048	(4)		54	%
Bulgurlu Mah. Bodrumi Cami Cikmazi 21
#6
Uskudar-Istanbul
Turkey

Dr. Mashhhoor Almadodi	5% shareholder		25,540,038	(5)		54	%
Beyotat Al-Amaal
Office 26 - Jeddah
the cross of Sary Street with King Street
Po BOX - 11193 / 21453
Saudi Arabiya

Abdulla Al-Faddagh	5% shareholder		13,584,993	(6)		29	%
Al-Rawda Block 5 Street 54 Building 11
Kuwait
PO Box 2483 Safat 13025

Ayedh Al-Hajeri	5% shareholder		2,400,000	(7)		5	%
Hadiya Block 1 Street 5 Building 44
Kuwait
PO Box 2483 Safat 13025

Total owned by officers and directors			27,924,425			59	%

(1) Based upon 47,295,000 shares outstanding as of the date of this report.

(2) Includes 2,374,377 shares held by Rasan Associates, LLC, a Texas limited liability company. Mr. Al-Humoud is a managing member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

(3) Includes 22,515,993 shares held by E&P Management and Development Co., LLC, a Texas limited liability company. Mr. Kaldirim is a managing member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

(4) Includes 3,024,045 shares held by Delta O&G, LLC, a Texas limited liability company. Dr. Kaldirim is a member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity. Includes also 22,515,993 shares held by E&P Management and Development Co., LLC, a Texas limited liability company. Dr. Kaldirim is a managing member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

(5) Includes 3,024,045 shares held by Delta O&G, LLC, a Texas limited liability company. Dr. Almadodi is a member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity. Includes also 22,515,993 shares held by E&P Management and Development Co., LLC, a Texas limited liability company. Dr. Almadodi is a managing member and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

(6) Includes 13,584,993shares held by Caldwell US, Inc., a Delaware corporation. Mr. Al-Faddagh is an officer, director and principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

(7) Includes 2,400,000 shares held by Rasan Energy. Mr. Al-Hajeri is a principal of the entity, and he may be deemed the beneficial owner or the shares held by such entity.

Risks and Uncertainties facing the Company

The Company has limited revenues to date, including during the recent six months ended June 30, 2013, and the Company may experience losses in the near term. The Company needs to maintain a steady operating structure, ensuring that expenses are contained such that profits are consistently achieved. In order to expand the Company’s business, the Company would likely require additional financing. As a company with limited revenues to date, management of the Company must continually develop and refine its strategies and goals in order to execute the business plan of the Company on a broad scale and expand the business.

One of the biggest challenges facing the Company will be in securing adequate capital to continue to expand its business and build a larger scale and more efficient set of operations. Secondarily, an ongoing challenge remains the maintenance of an efficient operating structure and business model. The Company must keep its expenses and the costs of employees at a minimum in order to generate a profit from the revenues that it receives. Third, in order to expand, the Company will need to continue to identify suitable exploration and development opportunities that can be realized at a reasonable cost.

Due to financial constraints and the current stage of the Company’s life, the Company has to date conducted limited advertising and marketing to reach customers. In addition, the Company has not yet located the sources of funding to develop the Company on a broader scale through acquisitions or other major partnerships. As the Company expands, the Company may need such partnerships and marketing campaigns to better build its business.

Risk Factors

The Company has generated revenues, but limited profits, to date.

The Company has generated limited profits to date. The business model of the Company involves significant costs, resulting in a low margin on revenues. Coupling this fact with operating expenses incurred by the Company, the Company has only generated a small amount of total profits in the past. The Company hopes that as its business expands that the scale of the enterprise would result in a higher gross margin and net margin.

No assurance of success in operations.

There is no assurance that the Company’s exploration or development activities will be successful. Moreover, there is no assurance that any of the Company’s operations will have any ability to realize profits.

The Company is an early-stage company with a limited operating history, and as such, any prospective investor may have difficulty in assessing the Company’s profitability or performance.

Because the Company is an early-stage company with a limited operating history, it could be difficult for any investor to assess the performance of the Company or to determine whether the Company will meet its projected business plan. The Company has limited financial results upon which an investor may judge its potential. As a company still in the early stages of its life, the Company may in the future experience under-capitalization, shortages, setbacks and many of the problems, delays and expenses encountered by any early-stage business. An investor will be required to make an investment decision based solely on the Company management’s history, its projected operations in light of the risks, the limited operations and financial results of the Company to date, and any expenses and uncertainties that may be encountered by one engaging in the Company’s industry.

The Company operates in a sector generally regarded with high risk.

The Company operates in the broader oil and gas exploration and development sector, which is an industry typically characterized by high risk. The success of the Company may vary widely based on the ability to successfully extract natural gas. Material risks can arise on account of Drilling/Mechanical Complications, Permit timing, sensitive nature of the market of the gas prices and variation in Reservoir Thickness etc.

The Company expects to incur additional expenses and may ultimately never be profitable.

The Company is an early-stage company and has a limited history of its operations. The Company will need to continue generating revenue in order to maintain sustained profitability. Ultimately, in spite of the Company’s best or reasonable efforts, the Company may have difficulty in generating revenues or remaining profitable.

The Company’s officers and directors beneficially own a majority of the Company’s common stock and, as a result, can exercise control over stockholder and corporate actions.

The officers and directors of the Company currently beneficially own approximately 59% of the Company’s outstanding common stock. As such, they will be able to control most matters requiring approval by stockholders, including the election of directors and approval of significant corporate transactions. This concentration of ownership may also have the effect of delaying or preventing a change in control, which in turn could have a material adverse effect on the market price of the Company’s common stock or prevent stockholders from realizing a premium over the market price for their Shares.

The Company depends on its management team to manage its business effectively.

The Company's future success is dependent in large part upon its ability to understand and develop the business plan and to attract and retain highly skilled management, operational and executive personnel. In particular, due to the relatively early stage of the Company's business, its future success is highly dependent on its officers, to provide the necessary experience and background to execute the Company's business plan. The loss of any officer’s services could impede, particularly initially as the Company builds a record and reputation, its ability to develop its objectives, and as such would negatively impact the Company's possible overall development.

Government regulation could negatively impact the business.

The Company’s business segments may be subject to various government regulations in the jurisdictions in which they operate. Due to the potential wide scope of the Company’s operations, the Company could be subject to regulation by various political and regulatory entities, including various local and municipal agencies and government sub-divisions. The Company may incur increased costs necessary to comply with existing and newly adopted laws and regulations or penalties for any failure to comply. The Company’s operations could be adversely affected, directly or indirectly, by existing or future laws and regulations relating to its business or industry.

The Company does not maintain certain insurance, including errors and omissions and indemnification insurance.

The Company has limited capital and, therefore, does not currently have a policy of insurance against liabilities arising out of the negligence of its officers and directors and/or deficiencies in any of its business operations. Even assuming that the Company obtained insurance, there is no assurance that such insurance coverage would be adequate to satisfy any potential claims made against the Company, its officers and directors, or its business operations. Any such liability which might arise could be substantial and may exceed the assets of the Company. The certificate of incorporation and by-laws of the Company provide for indemnification of officers and directors to the fullest extent permitted under Delaware law. Insofar as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers and controlling persons, it is the opinion of the Securities and Exchange Commission that such indemnification is against public policy, as expressed in the Act, and is therefore, unenforceable.

Intellectual property and/or trade secret protection may be inadequate.

The Company has applied for minimal intellectual property and trade secret protection in aspects of its business. There can be no assurance that the Company can obtain effective protection against unauthorized duplication or the introduction of substantially similar solutions and services. Further, there is no guarantee that intellectual property currently in place adequately protects the Company or its business and operations.

Shares of common stock in the Company may be subject to resale restrictions imposed by Rule 144 of the Securities and Exchange Commission

The shares of common stock held by current shareholders are considered “restricted securities” subject to the limitations of Rule 144 under the Securities Act. In general, securities may be sold pursuant to Rule 144 after being fully-paid and held for more than 12 months. Shares purchased in this Offering may be subject to Rule 144 resale restrictions, and accordingly, investors may be subject to such resale limitations.

Reliance upon Rule 144 to sell securities may be unavailable to the Company, due to its previous status as a shell company, and if Rule 144 is not available (pursuant to Rule 144(i)), certain shares of common stock may have no ability for sale or transfer until the Company is allowed to rely upon Rule 144 of the Securities and Exchange Commission

Rule 144 establishes specific criteria for determining whether a person is not engaged in a distribution of securities. Among other things, Rule 144 creates a safe harbor whereby a person satisfying the applicable conditions of the Rule 144 safe harbor is deemed not to be engaged in a distribution of the securities and therefore not an underwriter of the securities. If a purchaser of securities is unable to rely upon Rule 144 to sell securities (due to Rule 144(i)), then the securities must be registered or another exemption from registration must be found in order for the distribution of securities to be made. In the event that the securities are not registered or another exemption is not found, a purchaser of securities may not be able to sell or transfer the shares of common stock in the Company until such time as the Company is able rely upon Rule 144.

Pursuant to Rule 144(i), reliance upon Rule 144 is typically available for the resale of restricted or unrestricted securities that were initially issued by a reporting or non-reporting shell company (or an issuer that has been at any time previously a reporting or non-reporting shell company) only if the following conditions are met:

The issuer of the securities that was formerly a reporting or non-reporting shell company has ceased to be a shell company;

The issuer of the securities is subject to the reporting requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934;

The issuer of the securities has filed all reports and material required to be filed under Section 13 or 15(d) of the Exchange Act, as applicable, during the preceding 12 months (or for such shorter period that the issuer was required to file such reports and materials), other than Form 8-K reports; and

At least one year has elapsed from the time that the issuer filed current Form 10 type information with the Commission reflecting its status as an entity that is not a shell company.

ITEM 3.02 Unregistered Sales of Equity Securities

Recent Sales of Unregistered Securities

The Company has issued the following securities in the last three (3) years. All such securities were issued pursuant to an exemption from registration of the Securities Act of 1933, as amended, as a transaction by an issuer not involving any public offering, as noted below. Each of these transactions was issued as part of a private placement of securities by the Company in which (i) no general advertising or solicitation was used, and (ii) the investors purchasing securities were acquiring the same for investment purposes only, without a view to resale. Furthermore, no underwriters participated or effectuated any of the transactions specified below. Also, no underwriting discounts or commissions applied to any of the transactions set forth below. All potential investors were contacted personally and possessed at the time of their investment bona fide substantive, pre-existing business relationships with the Company and/or its officers, directors and affiliates. No potential investors were contacted through other means, and no general advertising or general solicitation was used to solicit any investors.

(1) On July 31, 2012, 10,000,000 shares of common stock were issued to Tiber Creek Corporation for total consideration paid of $1,000.00. Subsequently, on May 16, 2013, the Company redeemed an aggregate of 9,750,000 of these shares for the redemption price of $975.00

(2) On July 31, 2012, 10,000,000 shares of common stock were issued to MB Americus, LLC for total consideration paid of $1,000.00. Subsequently, on May 16, 2013, the Company redeemed an aggregate of 9,750,000 of these shares for the redemption price of $975.00

(3) On May 17, 2013, the Company issued 8,750,000 shares of its common stock pursuant to Section 4(2) of the Securities Act of 1933, as amended, as follows:

Names of Shareholders	No. of shares		Consideration

E&P Management and Development Co., LLC		3,821,396	$	382.14
Caldwell US, Inc.		1,774,000	$	177.40
Rasan Associates, LLC		100,000	$	10.00
Delta O&G, LLC		552,604	$	55.26
Rasan Private Equity		100,000	$	10.00
Rasan Energy		2,400,000	$	240.00
Univest		2,000	$	0.20

(4) Beginning in July 2013, shares of common stock were issued by the Company to the shareholders named below pursuant to executed subscription agreements under a Regulation D offering. The Company filed a Form D in August 2013.

Names of Shareholders	No. of shares		Consideration

Saad Salah Al-Ghanim		75,000	$	75,000
Ahmad Yousef Al-Khalaf		30,000	$	30,000
Yousef Yakoob Al-Salman		60,000	$	60,000
Al-Rawda Investment for Real Estate Development
and Projects Management Co.		500,000	$	500,000
Al Majmow International Trading Est.		100,000	$	100,000
Al Wadi Limited Co.		100,000	$	100,000
Mashhhoor Ali O Almadodi		80,000	$	80,000
Fatmah Abdulgader A Radwan		60,000	$	60,000
Hajar Mashhor A Almadodi		30,000	$	30,000
Zainab Mashhour A Almadodi		30,000	$	30,000
Khawlah Mashhoor A Almadodi		30,000	$	30,000
Aisha Mashhour A Almadodi		30,000	$	30,000
Ali Mashhoor A Almadodi		30,000	$	30,000
Mahmoud Mashhour A Almadodi		30,000	$	30,000
Fuad Hamed Al-Humoud		10,000	$	10,000
Hamad Fuad Al-Humoud		10,000	$	10,000
Abdulaziz Fuad Al-Humoud		10,000	$	10,000
Khaled Rashed Al-Hajeri		10,000	$	10,000
Fakhrieh Muhammad Al-Hajeri		10,000	$	10,000
Munirah Khaled Al-Hajeri		10,000	$	10,000
Rashed Khaled Al-Hajeri		10,000	$	10,000
Sarah Khaled Al-Hajeri		10,000	$	10,000
Muhammad Khaled Al-Hajeri		10,000	$	10,000
Ali Khaled Al-Hajeri		10,000	$	10,000
Abdullah Khaled Al-Hajeri		10,000	$	10,000

(5) On September 25, 2013, the Company issued 13,337,280 shares of common stock to members of EPCO in connection with the EPCO Acquisition, as follows:

Shareholder Name	Number of Shares

Caldwell US, Inc.		6,542,580
Rasan Associates, LLC		274,377
EPMD, LLC		5,057,885
Delta O&G, LLC		1,462,438

(6) On September 25, 2013, the Company issued 13,296,950 shares of common stock to retire debt of EPCO in connection with the EPCO Acquisition, as follows:

Shareholder Name	Number of Shares

Caldwell US, Inc.		210,528
Rasan Associates, LLC		2,000,000
Rasan Private Equity, Inc.		1,498,592
EPMD, LLC		8,578,827
Delta O&G, LLC		1,009,003

(7) On September 25, 2013, the Company issued 10,115,770 shares of common stock to members of Prestige in connection with the Prestige Acquisition, as follows:

Shareholder Name	Number of Shares

Caldwell US, Inc.		5,057,885
EPMD, LLC		5,057,885

ITEM 5.02 Change in Number of Directors; Election of Directors

In connection with the Acquisitions, the Company has expanded its size of the board of directors to four (4) seats. The term of each director shall be three (3) years.

ITEM 5.06 Change in Shell Company Status

The Company has acquired EPCO and Prestige, each of which has a defined business plan, and accordingly, the Company has commenced operations.

ITEM 9.01 Financial Statements and Exhibits

The audited financial statements of EPCO, including balance sheets as of June 30, 2013, December 31, 2012 and December 31, 2011, respectively, and the related statements of operations, changes in members’ equity (deficit), and cash flows for the six months ending June 30, 2013, year ending December 31, 2012 and the year ended December 31, 2011, respectively, are included herewith.

The audited financial statements of Prestige, including balance sheets as of June 30, 2013, December 31, 2012 and December 31, 2011, respectively, and the related statements of operations, changes in members’ equity (deficit), and cash flows for the six months ending June 30, 2013, year ending December 31, 2012 and the year ended December 31, 2011, respectively, are included herewith.

Exhibits

2.1+	Exchange Agreement
2.2.+	Exchange Agreement
10.1+	Coalbed Methane Lease
10.2+	Amendments to Coalbed Methane Lease
10.3+	Agreement with Regency Gas
10.4+	Amendments to Agreement with Regency Field Services
10.5	Agreement with Tiber Creek Corporation
10.6	Funding Arrangement with Rasan Private Equity
10.7	Employment Agreement of Stephen Spafford
10.8	Employment Agreement of Samta Gupta.

+ Previously filed with Form 8-K on October 4, 2013 as the same exhibit number as the exhibit number listed here, and incorporated herein by this reference.

Clay Thomas, P.C.

Certified Public Accountant

P.O. Box 311195

Houston, Texas 77231

(281) 253-9637 (office)

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of E & P Co., LLC

I have audited the accompanying statement of financial position of E & P Co., LLC as of June 30, 2013 and December 31, 2012, and the related statements of income, members’ equity and cash flows for each of the periods ending June 30, 2013 and December 31, 2012. E & P Co., LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on our audits.

I conducted my audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that I plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The company is not required to have, nor was I engaged to perform, an audit of its internal control over financial reporting. My audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the company’s internal control over financial reporting. Accordingly, I express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. I believe that my audits provide a reasonable basis for my opinion.

In my opinion, the financial statements referred to above present fairly, in all material respects, the financial position of E & P Co., LLC as of June 30, 2013 and December 31, 2012, and the results of its operations and its cash flows for each of the periods ending June 30, 2013 and December 31, 2012 in conformity with accounting principles generally accepted in the United States of America.

Houston, Texas

September 10, 2013

E & P Co., LLC

Statement of Financial Position

For the Years Ending June 30, 2013 and December 31, 2012

	2013			2012
ASSETS
Current Assets
Cash and Cash Equivalents		34,900			47,762
Accounts Receivable		655			933
Accounts Receivable- Related Party		-			751,231
Total Current Assets		35,555			799,926

Other Current Assets
Prepaid Expense		12,500			12,500
Refundable Deposits		11,204			11,204
Total Other Current Assets		23,704			23,704

Total Current Assets		59,259			823,630

Fixed Assets
Intangible Assets		8,157,352			-
Project Under Development		9,137,323			18,318,960
Property and Equipment		33,403			33,403
Furniture and Fixtures		39,236			39,236
Accumulated Depreciation		(70,470	)		(69,746	)
Total Fixed Assets		17,296,844			18,321,853

TOTAL ASSETS		17,356,103			19,145,483

LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable		177,447			640,075
Accounts Payable - Related Party		68,124			58,335
Accrued Expense		360,049			126,563
Total Accounts Payable		605,620			824,973

Other Current Liabilities
Notes Payable - Related Party		798,367			714,928
Total Other Current Liabilities		798,367			714,928
Total Current Liabilities		1,403,987			1,539,901

Long-Term Liabilities
Notes Payable - Related Party		9,092,467			12,937,500
Total Long-Term Liabilities		9,092,467			12,937,500

Total Liabilities		10,496,454			14,477,401

Equity
Members' Capital Accounts		6,859,649			4,668,082
Total Equity		6,859,649			4,668,082

TOTAL LIABILITIES & EQUITY		17,356,103			19,145,483

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Operations

For the Six Months Ending June 30, 2013 and 2012

	2013			2012

Ordinary Income
Income
Income		2,141			907
Total Income / (loss)		2,141			907

Direct Operating Costs
Drilling and Production Expense		-			268,394
Geographical and Geological		2,212			1,845
Royalty		19,594			113
Total Direct Operating Costs		21,806			270,352

General and Administrative Costs
Advertising		-			-
Bad Debt		107,302			-
Bank charges		453			165
Communication		412			3,386
Depreciation and Amortization		723			-
Employee Insurance		4,512			4,272
Insurance		8,708			8,167
License Fees		126			126
Miscellaneous		265			608
Office Equipment		930			600
Payroll		223,869			226,555
Professional Fees		358,174			218,058
Rent		19,692			20,784
Stationery		1,125			965
Taxes		4,028			-
Travel and Accommodations		11,375			16,706
Utilities		1,667			538

Total Professional Fees		743,361			500,930

Total Expense		765,167			771,282

Other Income/Expense
Other Income		-			-
Other Expense		-			12,019
Total Other Income/Expense		-			(12,019	)

Net Ordinary Income / (loss)		(763,026	)		(782,394	)

Net Income / (loss)		(763,026	)		(782,394	)

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Cash Flows

For the Six Months Ending June 30, 2013 and 2012

	2013			2012

Operating Activities
Net Income		(763,026	)		(782,394	)
Adjustments to reconcile Net Income
to net cash provided by operations:
Accounts Payable		(454,619	)		387,345
Accounts Receivable		751,231			(94,163	)
Accrued Expense		233,486			(12,036	)
Accrued Gas Sales Income		279			243
Credit Cards		(10	)		(27	)
Deposits		-			(3,928	)
Depreciation		723			-
Payroll Tax Liabilities		1,789			5,301
Net cash provided / (used) by Operating Activities		(230,147	)		(499,659	)

Investing Activities
Intangible Assets		(8,157,352	)		-
Project Under Development		9,181,636			-
Property and Equipment		-			(388	)
Net cash provided / (used) by investing activities:		1,024,284			(388	)

Financing Activities
Notes Payable		(3,761,593	)		555,000
Members' Equity		2,954,594			-
Net cash provided by Financing Activities		(806,999	)		555,000
Net cash increase for period		(12,862	)		54,953
Cash at Beginning of Period		47,762			3,188
Cash at end of period		34,900			58,141

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Members' Equity

For the Year Ending June 30, 2013

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance December 31, 2011		7,577,344		(3,803,785	)		3,773,559

Net Income/ (loss)		-		(513,999	)		(513,999	)

Balance June 30, 2012		7,577,344		(4,317,784	)		3,259,560

Member Investment		1,515,000		-			1,515,000

Net Income / (loss)		-		(106,478	)		(106,478	)

Balance December 31, 2012		9,092,344		(4,424,262	)		4,668,082

Member Investment		2,954,593		-			2,954,593

Net Income / (loss)		-		(763,026	)		(763,026	)

Balance June 30, 2013		12,046,937		(5,187,288	)		6,859,649

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of E & P Co., LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

The preparation of the financial statements in conformity with U.S. Generally Accepted Accounting Principles (GAAP) requires management to make estimates that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from these estimates.

Summary of Accounting Policies

Revenue Recognition. The Company generally produces and sells crude oil, natural gas and petroleum at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured.

Revenues from the production of natural gas properties in which the Company has an interest with other producers are recognized on the basis of the Company’s net working interest. Difference between actual production and net working interest volumes are not significant.

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Derivative Instruments. The Company does not currently make use of derivative instruments. When such use is enabled, the Company will not engage in speculative derivative activities or derivative trading activities, nor use derivatives with leveraged features. Should the Company enter into derivative transactions, it will be to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions.

The gains and losses resulting from changes in the fair value of derivatives will be recorded in income. In some cases, the Company may designate derivatives as fair value hedges, in which the gains and losses are offset in income by the gains and losses arising from changes in the fair value of the underlying hedged item.

Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Inventories. Crude oil, products and merchandise inventories are carried at the lower of current market value or cost (generally determined under the last-in, first-out method – LIFO). Inventory costs include expenditures and other charges (including depreciation) directly and indirectly incurred in bringing inventory to its existing condition and location. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory costs. Inventories of materials and supplies are valued at cost or less.

Property, Plant and Equipment. Depreciation, depletion, and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production or the straight-line method, which is based on an estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired.

Interest costs incurred to finance expenditures during the construction phase of multi-year projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets.

The Company uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-of-production method.

The Company carries as assets exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred.

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates based on the amount of proved reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods.

Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transactions points at the outlet valve on the lease or field storage tank.

Production costs are expensed as incurred. Production involves lifting oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Company’s wells and related equipment and facilities. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies, and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity.

Proved oil and gas properties held by the Company are reviewed for impairment whenever events or changes in circumstances indicate the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets.

The Company estimates future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices, refining and chemical margins, and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments.

Impairment analyses are generally based on proved reserves. Where probable reserves exist, an approximately risk-adjusted amount of these reserves may be included in the impairment evaluation. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value.

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Company expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually.

Gains on sales of proved and unproved property are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the Company.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Asset Retirement Obligations and Environmental Liabilities. The Company incurs retirement obligations for certain assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically at the time the assets are installed. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value.

Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted.

Accounting Changes

The Company did not adopt authoritative guidance in 2013 that had a material impact on the Company’s financial statements.

Cash Flow Information

The Statement of Cash Flows provides information about changes in cash and cash equivalents. Highly liquid investments with maturities of three months or less when acquired are classified as cash equivalents.

Long-Term Debt

At June 30, 2013 and December 31, 2012, long-term debt consisted of $9,092,467 and $12,937,500, respectively. Summarized long-term debt at June 30, 2013 and at year end 2012 are shown in the table below:

	June 30, 2013		December 31, 2012
E & P Management and Development, LLC		6,090,967		6,000,000
Prestige O & G, LLC		-		4,537,500
Caldwell (US) Inc.		-		-
Mashhoor Almadodi		517,500		-
Rasan Private Equity		2,484,000		2,400,000
Total		9,092,467		12,937,500

Related Party Transactions

Summarized transactions involving related parties at June 30, 2013 and December 31, 2012 are shown in the table below:

Accounts Receivable

	June 30, 2013			December 31, 2012
Balance at January 1		751,230			357,515
E & P Co. International, LLC		(496,954	)		401,925
Caldwell (US) Inc.		(21,066	)		6,270
E & P Management and Development, LLC		(40,645	)		5,900
Prestige O & G, LLC		(189,725	)		20,934
Delta O & G, LLC		(708	)		400
Rasan Private Equity		(2,132	)		2,132
UniVest Inc.		-			(43,845	)

Total		-			751,231

Notes Payable

	June 30, 2013			December 31, 2012
Balance at January 1		13,652,428			12,675,000
Rasan Private Equity		534,000			400,000
Prestige O & G, LLC		(4,537,500	)		412,500
EPMD, LLC		90,967			-
Mashhoor Almadodi		216,392			500,000
Osman Kaldirim, Sr.		(150,000	)		-
Rasan Associates, LLC		(8,315	)		39,928
Rasan Energy		80,000			25,000
Caldwell (US) Inc.		12,862			(400,000	)
Total		9,890,834			13,652,428

Accounts Payable

	June 30, 2013		December 31, 2012
Balance at January 1		58,335		22,476
Rasan Holding		-		26,490
Osman Kaldirim, Sr.		6,414		9,369
Fuad AlHumoud		1,375		-
Robert Leidich		2,000		-
Total		68,124		58,335

On June 30, 2013, Prestige O & G, LLC, a shareholder in the Company had its interest redeemed by the Company though the transfer of a comparable interest in the Company’s Project Under Development. Subsequent to this transaction, E & P Co., LLC and Prestige O & G, LLC executed a joint operating agreement involving that asset.

Investments, Advances and Long-Term Receivables

The Company had no investments, advances, or long-term receivables as of September 30, 2013 and December 31, 2012.

Litigation and other Contingencies

A variety of claims have been made against E & P Co., LLC in a currently pending lawsuit. Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The Company accrues an undiscounted liability for those contingencies where the incurrence of loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For purposes of our contingency disclosures, “significant” includes material matters as well as other matters which management believes should be disclosed. E & P Co., LLC will continue to defend itself vigorously in these matters. Based on a consideration of all relevant facts and circumstances, the Company does not believe the ultimate outcome of any currently pending lawsuit against E & P Co., LLC will have a material adverse effect upon the Company’s operations, financial condition, or financial statements taken as a whole.

On April 16, 2009, Noram Drilling Company filed an original complaint against E & P Co. International, LLC and E & P Co., LLC in the 37^th District Court of Louisiana, arguing E & P Co., LLC was liable for breach of contract by E & P Co., LLC under the theory of single enterprise liability. The Company argues no such single enterprise liability exists as the contract is to be construed under Texas law. On January 16, 2013, the 37^th District Court in the Parish of Caldwell, Louisiana, the court granted E & P Co., LLC’s Motion for Summary Judgment, holding the Company not to be a party to the drilling contract. The Court further denied NorAm’s Motion for Summary Judgment for damages. On December 11, 2013, the Court of Appeals of the Second Circuit of the State of Louisiana affirmed the trial court’s finding.

Income, Sales-Based and Other Taxes

The Company is organized as a Limited Liability Company under the laws of the State of Texas. For federal income tax purposes, the Company is treated as a partnership with all income and expense flowing through to the members. As such, the Company has no federal income tax liability.

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

Supplemental Information on Oil and Gas Exploration and Production

The results of operations for producing activities shown below do not include earnings from nonoperating activities.

Results of Operations for the Six Months Ending	June 30, 2013			June 30, 2012
Revenue
Sales to third parties		2,141			907

Production costs excluding taxes		2,212			1,845
Exploration expenses incurred		-			268,394
Exploration expenses capitalized at December 31, 2012		-			(268,394	)
Taxes other than income		-			-
Related income tax		-			-
Results of producing activities		(71	)		(938	)

Management’s judgment regarding the project’s capitalization of exploration well costs is based upon its current inability to estimate reserves. Currently, the project requires additional investment and approximately six months production history at substantially higher rates before an appropriate valuation of proved reserves may be made. The Company anticipates the following costs necessary to achieve proven reserve status of which E & P Co., LLC will be responsible for its interest accordingly:

Description	Cost
Addition of new saltwater disposal well		1,000,000
Re-drill Well No. 1		1,000,000
Replace pumps on Wells No. 4 and 5		200,000
Proved reserves valuation		25,000
		-
Net costs		2,225,000

As of June 31, 2013 and December 31, 2012, the amounts of capitalized exploratory well costs pending determination of proved reserves was as follows:

Capitalized Costs	June 30, 2013		December 31, 2012
Property (acreage)
Unproved		30,322		30,322
Total property costs		30,322		30,322
Producing assets		9,107,001		18,288,638
Incomplete construction		-		-
Total capitalized		-		-
Accumulated depreciation and depletion		-		-
Net capitalized costs		9,137,323		18,318,960

The aging of amounts of capitalized well costs and number of projects are as follows:

Period Ending December 31	Well Costs Capitalized for the Period			Number of Projects
2008		5,536,873		1
2009		2,986,906		1
2010		3,544,207		1
2011		5,285,613		1
2012		965,360		1
June 30, 2013		517,881		1
Redemption by Prestige O & G, LLC		(9,699,517	)
Total		9,137,323

10.

Subsequent Events

In the third quarter of 2013, holders of long-term notes payable elected to convert the debt owed to them into equity in the Company. These transactions extinguished all long-term debt owed by the Company.

The Company will soon initiate the process of identifying a drilling company for the drilling of the disposal well and anticipates production in paying quantities with an appropriate valuation of reserved to follow shortly thereafter.

Clay Thomas, P.C.

Certified Public Accountant

P.O. Box 311195

Houston, Texas 77231

(281) 253-9637 (office)

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of E & P Co., LLC

I have audited the accompanying Statement of Financial Position of E & P Co., LLC as of December 31, 2012 and 2011, and the related Statements of Operations, Changes of Members’ Equity and Cash Flows for each of the two years ending December 31, 2012. E & P Co., LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on my audits.

In my opinion, the financial statements referred to above present fairly, in all material respects, the Statement of Financial Position of E & P Co., LLC as of December 31, 2012 and 2011, and the results of its Statements of Operations, Changes in Members’ Equity and its Cash Flows for each of the two years ending December 31, 2012 in conformity with accounting principles generally accepted in the United States of America.

Houston, Texas

February 12, 2013

E & P Co., LLC

Statement of Financial Position

For the Years Ending December 31, 2012 and 2011

	2012			2011
ASSETS
Current Assets
Cash and Cash Equivalents		47,762			(93,821	)
Accounts Receivable		933			243
Accounts Receivable - Related Parties		751,231			357,515
Total Current Assets		799,926			263,937

Other Current Assets
Prepaid Expense		12,500			24,852
Refundable Deposits		11,204			7,276
Total Other Current Assets		23,704			32,128

Total Current Assets		823,630			296,065

Fixed Assets
Project Under Development		18,318,960			17,353,603
Property, Plant and Equipment		2,893			5,399
Total Fixed Assets		18,321,853			17,359,002

Non-Current Assets
Investment Property		-			1,542,510
Total Non-Current Assets		-			1,542,510

TOTAL ASSETS		19,145,483			19,197,577
LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable		640,075			94,036
Accounts Payable - Related Parties		58,335			22,476
Accrued Expense		126,563			415,156
Total Accounts Payable		824,973			531,668

Other Current Liabilities
Notes Payable - Related Parties		714,928			2,367,350
Total Other Current Liabilities		714,928			2,367,350
Total Current Liabilities		1,539,901			2,899,018

Long-Term Liabilities
Notes Payable - Related Parties		12,937,500			12,525,000
Total Long-Term Liabilities		12,937,500			12,525,000

Total Liabilities		14,477,401			15,424,018

Equity
Members' Capital Accounts		9,092,344			7,577,344
Retained Earnings		(4,424,262	)		(3,803,785	)
Total Equity		4,668,082			3,773,559
TOTAL LIABILITIES & EQUITY		19,145,483			19,197,577

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Operations

For the Years Ending December 31, 2012 and 2011

	2012			2011

Ordinary Income
Income
Income		4,420			13,046
Total Income / (loss)		4,420			13,046
		4,420			13,046
Direct Operating Costs
Geographical and Geological		1,844			1,752
Royalty		589			2,124
Total Direct Operating Costs		2,433			3,876

General and Administrative Costs
Advertising and Promotion		-			2,187
Bank charges		345			804
Depreciation and Amortization		2,893			4,851
Insurance		29,436			15,227
Legal		133,416			51,737
License Fees		124			2,397
Miscellaneous		1,187			1,863
Payroll		590,587			469,995
Professional Fees		15,481			39,630
Property Tax		332			1,721
Rent		29,568			24,000
Supplies		5,384			7,278
Telephone		6,395			7,927
Travel		47,880			102,642
Utilities		962			1,116
Total General and Administrative Cost		863,990			733,375

Total Expense		866,423			737,251

Other Income/Expense
Other Income		241,526			41,150
Total Other Income/Expense		241,526			41,150

Net Other Income / (loss)		241,526			41,150

Net Income / (loss)		(620,477	)		(683,055	)

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Cash Flows

For the Years Ending December 31, 2012 and 2011

Increase (Decrease) in Cash and Cash Equivalents

	2012			2011

Operating Activities
Net Income		(620,477	)		(683,055	)
Adjustments to reconcile Net Income to net cash provided by operations:
Accounts Payable		573,616			(243,564	)
Accounts Receivable		(437,561	)		(129,979	)
Accrued Expense		113,226			(4,743	)
Accrued Gas Sales Income		(690	)		-
Accrued Interest Income		43,844			(24,806	)
Accrued Interest Expense		(401,820	)		-
Credit Cards		(17	)		(613	)
Deposits		(3,928	)		(7,276	)
Depreciation		2,893			4,851
Investments		1,542,510			-
Payroll Tax Liabilities		8,305			(24,784	)
Prepaid Expense		12,352			-
Restricted Cash		-			161,000
Net cash provided / (used) by Operating Activities		832,253			(952,969	)

Investing Activities
Purchase of Certificate of Deposit		-			-
Project Under Development		(965,360	)		(5,285,613	)
Property and Equipment		(388	)		(1,337	)
Net cash provided / (used) by investing activities:		(965,748	)		(5,286,950	)

Financing Activities
Investment from Members		1,515,000			4,000,000
Notes Payable		(1,239,922	)		1,537,350
Members' Equity		-			-
Net cash provided by Financing Activities		275,078			5,537,350
Net cash increase for period		141,583			(702,569	)
Cash at Beginning of Period		(93,821	)		608,748
Cash at end of period		47,762			(93,821	)

Supplemental Disclosures

Cash paid during the year for:
Interest (net of amount capitalized)		-			-
Income Taxes		-			-

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Members' Equity

For the Year Ending December 31, 2012

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance January 1, 2010		3,577,344		(2,245,982	)		1,331,362

Net Income / (loss)		-		(874,748	)		(874,748	)

Balance December 31, 2010		3,577,344		(3,120,730	)		456,614

Member Investment		4,000,000		-			4,000,000

Net Income / (loss)		-		(683,055	)		(683,055	)

Balance December 31, 2011		7,577,344		(3,803,785	)		3,773,559

Member Investment		1,515,000					1,515,000

Net Income/(loss)				(620,477	)		(620,477	)

Balance December 31, 2012		9,092,344		(4,424,262	)		4,668,082

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of E & P Co., LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

Summary of Accounting Policies

Revenue Recognition. The Company generally sells crude oil, natural gas and petroleum at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, process are fixed or determinable and collectability is reasonably assured.

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Inventories. Crude oil, products and merchandise inventories are carried a the lower of current market value or cost (generally determined under the last-in, first-out method – LIFO). Inventory costs include expenditures and other charges (including depreciation) directly and indirectly incurred in bringing inventory to its existing condition and location. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory costs. Inventories of materials and supplies are valued at cost or less.

The Company carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred.

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Accounting Changes

The Company did not adopt authoritative guidance in 2012 that had a material impact on the Company’s financial statements.

Cash Flow Information

Long-Term Debt

At December 31, 2012, long-term debt consisted of $12,937,500 due in U.S. dollars. This amount excludes that portion of long-term debt which matures within one year and is included in current liabilities.

Summarized long-term debt at year end 2012 and 2011 are shown in the table below:

	2012		2011
E & P Management and Development, LLC		6,000,000		6,000,000
Prestige O & G, LLC		4,537,500		4,125,000
Caldwell (US) Inc.		-		400,000
Rasan Private Equity		2,400,000		2,000,000
Total		12,937,500		12,525,000

Related Party Transactions

Summarized transactions involving related parties at year end 2012 and 2011 are shown in the table below:

Accounts Receivable

	2012			2011
Balance at January 1		357,515			200,390
E & P Co. International, LLC		401,925			95,029
Caldwell (US) Inc.		6,270			6,899
E & P Management and Development, LLC		5,900			7,274
Prestige O & G, LLC		20,934			23,052
Delta O & G, LLC		400			308
Rasan Private Equity		2,132			-
UniVest, Inc.		(43,845	)		24,563

At December 31		751,231			357,515

Notes Payable

	2012			2011
Balance at January 1		14,892,350			13,355,000
Rasan Private Equity		(1,317,350	)		112,350
Prestige O & G, LLC		412,500			375,000
Mashhoor Almadodi		-			500,000
Osman Kaldirim, Sr.		-			150,000
Rasan Associates, LLC		39,928
Rasan Energy		25,000			400,000
Caldwell (US) Inc.		(400,000	)		-
At December 31		13,652,428			14,892,350

Accounts Payable

	2011		2011
Balance at January 1		22,476		31,438
Osman Kaldirim, Sr.		9,369
Rasan Holding		26,490		(8,962	)
Total		58,335		22,476

Investments, Advances and Long-Term Receivables

The balance of investments at year end 2012 and 2011 was $0 and $1,542,510, respectively. The investments were held with Univest, Inc., an entity located in the Cayman Islands, for the purpose of participating in investment transactions in compliance with Islamic Sharia’s principles. The investment agreement is subject to the laws of the State of New York to the extent they do not conflict with the provisions of Islamic Sharia principles. Venue for any dispute as to the terms of the agreement is subject to arbitration with a duly authorized representative of the American Arbitration Association.

In 2012, Rasan Private Equity assumed ownership and possession of the investment in the Univest account in satisfaction of its outstanding loan.

Litigation and other Contingencies

Income, Sales-Based and Other Taxes

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

Supplemental Information on Oil and Gas Exploration and Production

The results of operations for producing activities shown below do not include earnings from nonoperating activities.

Results of Operations	2012		2011
Revenue
Sales to third parties		4,420		13,046

Production costs excluding taxes		2,433		3,876
Exploration expenses		-		-
Depreciation and depletion		-		-
Taxes other than income		-		-
Related income tax		-		-
Results of producing activities		1,987		9,170

Capitalized Costs	2012		2011
Property (acreage)
Unproved		29,322		19,322
Total property costs		29,322		19,322
Producing assets		18,289,638		17,334,281
Incomplete construction		-		-
Total capitalized		-		-
Accumulated depreciation and depletion		-		-
Net capitalized costs		18,318,960		17,353,603

The aging of amounts of capitalized well costs and number of projects are as follows:

Period Ending December 31	Well Costs Capitalized for the Period		Number of Projects
2008		5,536,873		1
2009		2,986,906		1
2010		3,544,207		1
2011		5,285,614		1
2012		965,360		1

Total		18,318,960

10.

Subsequent Events

On January 16, 2013, the 37^th District Court in the Parish of Caldwell, Louisiana, the court granted E & P Co., LLC’s Motion for Summary Judgment, holding the Company not to be a party to the drilling contract. The Court further denied NorAm’s Motion for Summary Judgment for damages.

Clay Thomas, P.C.

Certified Public Accountant

8302 Hausman Road

No. 518

San Antonio, Texas 78249

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of E & P Co., LLC

I have audited the accompanying Statement of Financial Position of E & P Co., LLC as of December 31, 2011 and 2010, and the related Statements of Operations, Changes of Members’ Equity and Cash Flows for each of the two years ending December 31, 2011. E & P Co., LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on my audits.

In my opinion, the financial statements referred to above present fairly, in all material respects, the Statement of Financial Position of E & P Co., LLC as of December 31, 2011 and 2010, and the results of its Statements of Operations, Changes in Members’ Equity and its Cash Flows for each of the two years ending December 31, 2011 in conformity with accounting principles generally accepted in the United States of America.

San Antonio, Texas

April 11, 2012

E & P Co., LLC

Statement of Financial Position

For the Years Ending December 31, 2011 and 2010

	2011			2010
ASSETS
Current Assets
Cash and Cash Equivalents		(93,821	)		769,749
Accounts Receivable		243			2,581
Accounts Receivable - Related Parties		357,515			200,390
Total Current Assets		263,937			972,720

Other Current Assets
Prepaid Expense		24,852			24,852
Refundable Deposits		7,276			-
Total Other Current Assets		32,128			24,852

Total Current Assets		296,065			997,572

Fixed Assets
Project Under Development		17,353,603			12,067,986
Property, Plant and Equipment		5,399			8,913
Total Fixed Assets		17,359,002			12,076,899

Non-Current Assets
Investment Property		1,542,510			1,542,510
Total Non-Current Assets		1,542,510			1,542,510

TOTAL ASSETS		19,197,577			14,616,981
LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable		94,036			328,638
Accounts Payable - Related Parties		22,476			31,438
Accrued Expense		415,156			445,291
Total Accounts Payable		531,668			805,367

Other Current Liabilities
Notes Payable - Related Parties		2,367,350			1,605,000
Total Other Current Liabilities		2,367,350			1,605,000
Total Current Liabilities		2,899,018			2,410,367

Long-Term Liabilities
Notes Payable - Related Parties		12,525,000			11,750,000
Total Long-Term Liabilities		12,525,000			11,750,000

Total Liabilities		15,424,018			14,160,367

Equity
Members' Capital Accounts		7,577,344			3,577,344
Retained Earnings		(3,803,785	)		(3,120,730	)
Total Equity		3,773,559			456,614
TOTAL LIABILITIES & EQUITY		19,197,577			14,616,981

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Operations

For the Years Ending December 31, 2011 and 2010

	2011			2010

Ordinary Income
Income
Income		13,046			2,582
Total Income / (loss)		13,046			2,582
		13,046			2,582
Direct Operating Costs
Geographical and Geological		1,752			3,135
Royalty		2,124			413
Total Direct Operating Costs		3,876			3,548

General and Administrative Costs
Advertising and Promotion		2,187			1,656
Bad Debt		-			108,265
Bank charges		804			630
Depreciation and Amortization		4,851			7,663
Insurance		15,227			18,775
Legal		51,737			56,658
License Fees		2,397			9,676
Miscellaneous		1,863			1,491
Payroll		469,995			398,319
Professional Fees		39,630			157,807
Property Tax		1,721			-
Rent		24,000			24,000
Supplies		7,278			13,188
Telephone		7,927			8,076
Travel		102,642			116,582
Utilities		1,116			837
Total General and Administrative Cost		733,375			923,623

Total Expense		737,251			927,171

Other Income/Expense
Other Income		41,150			49,841
Total Other Income/Expense		41,150			49,841

Net Other Income / (loss)		41,150			49,841

Net Income / (loss)		(683,055	)		(874,748	)

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Cash Flows

For the Years Ending December 31, 2011 and 2010

Increase (Decrease) in Cash and Cash Equivalents

	2011			2010

Operating Activities
Net Income		(683,055	)		(874,748	)
Adjustments to reconcile Net Income to net cash provided by operations:
Accounts Payable		(243,564	)		(729,367	)
Accounts Receivable		(129,979	)		49,840
Accrued Expense		(4,743	)		487,730
Accrued Interest Income		(24,806	)		(6,640	)
Credit Cards		(613	)		(235	)
Deposits		(7,276	)		-
Depreciation		4,851			7,663
Payroll Tax Liabilities		(24,784	)		11,855
Prepaid Expense		-			654
Restricted Cash		161,000			(161,000	)
Net cash provided / (used) by Operating Activities		(952,969	)		(1,214,248	)

Investing Activities
Purchase of Certificate of Deposit		-			(200	)
Project Under Development		(5,285,613	)		(3,544,207	)
Property and Equipment		(1,337	)		(3,583	)
Net cash provided / (used) by investing activities:		(5,286,950	)		(3,547,990	)

Financing Activities
Investment from Members		4,000,000			-
Notes Payable		1,537,350			5,000,000
Members' Equity		-			-
Net cash provided by Financing Activities		5,537,350			5,000,000
Net cash increase for period		(702,569	)		237,762
Cash at Beginning of Period		608,748			370,987
Cash at end of period		(93,821	)		608,749

Supplemental Disclosures

Cash paid during the year for:
Interest (net of amount capitalized)		-			-
Income Taxes		-			-

See accompanying notes to the financial statements.

E & P Co., LLC

Statement of Members' Equity

For the Year Ending December 31, 2011

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance January 1, 2010		3,577,344		(2,245,982	)		1,331,362

Net Income / (loss)		-		(874,748	)		(874,748	)

Balance December 31, 2010		3,577,344		(3,120,730	)		456,614

Member Investment		4,000,000		-			4,000,000

Net Income / (loss)		-		(683,055	)		(683,055	)

Balance December 31, 2011		7,577,344		(3,803,785	)		3,773,559

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of E & P Co., LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

Summary of Accounting Policies

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Accounting Changes

The Company did not adopt authoritative guidance in 2011 that had a material impact on the Company’s financial statements.

Cash Flow Information

Long-Term Debt

At December 31, 2011, long-term debt consisted of $6 million due in U.S. dollars. This amount excludes that portion of long-term debt which matures within one year and is included in current liabilities.

Summarized long-term debt at year end 2011 and 2010 are shown in the table below:

	2011		2010
E & P Management and Development, LLC		6,000,000		6,000,000
Prestige O & G, LLC		4,125,000		3,750,000
Caldwell (US) Inc.		400,000		-
Rasan Private Equity		2,000,000		2,000,000
Total		12,525,000		11,750,000

Related Party Transactions

Summarized transactions involving related parties at year end 2011 and 2010 are shown in the table below:

Accounts Receivable

	2011		2010
Balance at January 1		200,390		246,170
E & P Co. International, LLC		95,029		(93,047	)
Caldwell (US) Inc.		6,899		6,298
E & P Management and Development, LLC		7,274		16,088
Prestige O & G, LLC		23,052		18,240
Delta O & G, LLC		308		-
UniVest, Inc.		24,563		6,641

At December 31		357,515		200,390

Notes Payable

	2011		2010
Balance at January 1		13,355,000		8,250,000
Rasan Private Equity		112,350		2,105,000
Prestige O & G, LLC		375,000		3,000,000
Mashhoor Almadodi		500,000		-
Osman Kaldirim, Sr.		150,000		-
Rasan Energy		400,000		-

At December 31		14,892,350		13,355,000

Accounts Payable

	2011			2010
Balance at January 1		31,438			9,326
Rasan Holding		(8,962	)		22,112
Total		22,476			31,438

Investments, Advances and Long-Term Receivables

The balance of investments at year end 2011 and 2010 was $1,542,510 and $1,542,510, respectively. The investments were held with Univest, Inc., an entity located in the Cayman Islands, for the purpose of participating in investment transactions in compliance with Islamic Sharia’s principles. The investment agreement is subject to the laws of the State of New York to the extent they do not conflict with the provisions of Islamic Sharia principles. Venue for any dispute as to the terms of the agreement is subject to arbitration with a duly authorized representative of the American Arbitration Association.

Litigation and other Contingencies

Income, Sales-Based and Other Taxes

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

Supplemental Information on Oil and Gas Exploration and Production

The results of operations for producing activities shown below do not include earnings from nonoperating activities.

Results of Operations	2011		2010
Revenue
Sales to third parties		13,046		2,582

Production costs excluding taxes		3,876		3,548
Exploration expenses		-		-
Depreciation and depletion		-		-
Taxes other than income		-		-
Related income tax		-		-
Results of producing activities		9,170		(966	)

As of December 31, 2011 and December 31, 2010, the amounts of capitalized exploratory well costs pending determination of proved reserves was as follows:

Capitalized Costs	2011		2010
Property (acreage)
Unproved		19,322		19,322
Total property costs		19,322		19,322
Producing assets		17,334,281		12,048,664
Incomplete construction		-		-
Total capitalized		-		-
Accumulated depreciation and depletion		-		-
Net capitalized costs		17,353,603		12,067,986

The aging of amounts of capitalized well costs and number of projects are as follows:

Period Ending December 31	Well Costs Capitalized for the Period		Number of Projects
2008		5,536,873	1
2009		2,986,906	1
2010		3,544,207	1
2011		5,285,617	1

Total		17,353,603

10.

Subsequent Events

None noted.

Clay Thomas, P.C.

Certified Public Accountant

P.O. Box 311195

Houston, Texas 77231

(281) 253-9637 (office)

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of Prestige O & G, LLC

I have audited the accompanying statement of financial position of Prestige O & G, LLC as of June 30, 2013 and December 31, 2012, and the related statements of income, members’ equity and cash flows for each of the periods ending June 30, 2013 and December 31, 2012. Prestige O & G, LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on our audits.

In my opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Prestige O & G, LLC as of June 30, 2013 and December 31, 2012, and the results of its operations and its cash flows for each of the periods ending June 30, 2013 and December 31, 2012 in conformity with accounting principles generally accepted in the United States of America.

Houston, Texas

September 10, 2013

Prestige O & G, LLC

Statement of Financial Position

For the Period Ending June 30, 2013 and December 31, 2012

	June 30,		December 31,
	2013		2012
ASSETS
Current Assets
Cash and Cash Equivalents		5,338		5,338
Notes Receivable - Related Parties		-		4,537,500
Total Current Assets		5,338		4,542,838

Other Current Assets
Accrued Gas Sales Income		-		-
Prepaid Expense		-		1,309
Refundable Deposits		-		-
Total Other Current Assets		-		1,309

Total Current Assets		5,338		4,544,147

Fixed Assets
Investment in E & P Co.		-		5,019,633
Project Under Development		10,049,517		350,000
Total Fixed Assets		10,049,517		5,369,633

TOTAL ASSETS		10,054,855		9,913,780

LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable - Related Parties		-		189,725
Accrued Expense		-		5,900
Payroll Tax Liabilities		-		-
Total Accounts Payable		-		195,625

Total Current Liabilities		-		195,625


Total Liabilities		-		195,625

Equity
Members' Capital Accounts		10,054,855		9,718,155
Total Equity		10,054,855		9,718,155

TOTAL LIABILITIES & EQUITY		10,054,855		9,913,780

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Operations

For the Six Month Period Ending June 30, 2013 and 2012

	2013			2012

Ordinary Income
Income
Share of Results in Associate		(271,317	)		-
Total Income / (loss)		(271,317	)		-

General and Administrative Costs
Miscellaneous		-			-
Professional Fees		-			-
Rent		5,237			1,000

Total G & A Costs		5,237			1,000

Total Expense		5,237			1,000

Other Income/Expense
Other Income		158,813			-
Other Expense		-			-
Total Other Income/Expense		158,813			-

Net Ordinary Income / (loss)		(117,741	)		(1,000	)

Net Income / (loss)		(117,741	)		(1,000	)

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Cash Flows

For the Six Month Period Ending June 30, 2013 and 2012

	2013			2012

Operating Activities
Net Income		(117,741	)		(1,000	)
Adjustments to reconcile Net Income to net cash provided by operations:
Accounts Payable		(189,726	)		-
Accrued Expense		(5,900	)		-
Accrued Interest Income		-			-
Notes Receivable		4,537,500			-
Prepaid Expense		1,309			1,000
Net cash provided / (used) by Operating Activities		4,225,442			-

Investing Activities
Investment in E & P Co., LLC		5,474,075			-
Project Under Development		(9,699,517	)		-
Net cash provided / (used) by investing activities:		(4,225,442	)		-

Financing Activities
Shareholders' Equity		-			-
Net cash provided by Financing Activities		-			-
Net cash increase for period		-			-
Cash at Beginning of Period		5,338			5,338
Cash at end of period		5,338			5,338

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Members' Equity

For the Period Ending June 30, 2013

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance December 31, 2011		9,058,790		630,347			9,689,137

Net Income / (loss)		-		29,018			29,018

Balance December 31, 2012		9,058,790		659,365			9,718,155

Member Investment		454,441		-			454,441

Net Income / (loss)		-		(117,741	)		(117,741	)

Balance June 30, 2013		9,513,231		541,624			10,054,855

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of Prestige O & G., LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

1. Summary of Accounting Policies

Revenue Recognition. The Company generally produces and sells crude oil, natural gas and petroleum at prevailing market prices through a Joint Operating Agreement with E & P Co., LLC. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured.

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

2. Accounting Changes

The Company did not adopt authoritative guidance in 2013 that had a material impact on the Company’s financial statements.

3. Cash Flow Information

4. Long-Term Debt

At June 30, 2013 and December 31, 2012, the Company held no long-term debt.

5. Related Party Transactions

Summarized transactions involving related parties at June 30, 2013 and December 31, 2012 are shown in the table below:

Notes Receivable

	June 30, 2013			December 31, 2012
Balance at January 1		4,537,500			4,125,000
E & P Co., LLC		(4,537,500	)		412,500
Total		-			4,537,500

Accounts Payable

	June 30, 2013			December 31, 2012
Balance at January 1		189,726			168,792
E & P Co., LLC		(189,726	)		20,934
Total		-			189,726

On June 30, 2013, The Company, a shareholder in the E & P Co., LLC had its interest redeemed though the transfer of a comparable interest of E & P Co., LLC’s Project Under Development. Subsequent to this transaction, the Company and E & P Co., LLC executed a joint operating agreement involving that asset.

6. Investments, Advances and Long-Term Receivables

The Company had no investments, advances, or long-term receivables as of September 30, 2013 and December 31, 2012.

7. Litigation and other Contingencies

The Company has not been the subject of any litigation. The Company’s management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The Company will accrue an undiscounted liability for those contingencies where the incurrence of loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. The Company will soon initiate the process of identifying a drilling company for the drilling of the disposal well and anticipates production in paying quantities with an appropriate valuation of reserved to follow shortly thereafter.

A variety of claims have been made against E & P Co., LLC, a related party, in a currently pending lawsuit. E & P Co., LLC will continue to defend itself vigorously in these matters. Based on a consideration of all relevant facts and circumstances, the Company does not believe the ultimate outcome of any currently pending lawsuit against E & P Co., LLC will have a material adverse effect upon the Company’s operations, financial condition, or financial statements taken as a whole.

8. Income, Sales-Based and Other Taxes

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

9. Supplemental Information on Oil and Gas Exploration and Production

The results of operations for producing activities shown below do not include earnings from nonoperating activities. Since the acquisition of an interest in E & P Co., LLC’s Project Under Development, occurred June 30, 2013, results for oil and gas exploration and production operations are not yet available.

Management’s judgment regarding the project’s capitalization of exploration well costs is based upon its current inability to estimate reserves. Currently, the project requires additional investment and approximately six months production history at substantially higher rates before an appropriate valuation of proved reserves may be made. The Company anticipates the following costs necessary to achieve proven reserve status of which Prestige O & G will be responsible for its interest accordingly:

Description	Cost
Addition of new saltwater disposal well		1,000,000
Re-drill Well No. 1		1,000,000
Replace pumps on Wells No. 4 and 5		200,000
Proved reserves valuation		25,000
		-
Net costs		2,225,000

The Company’s interest in the Project Under Development are as follows. As of June 31, 2013 and December 31, 2012, the amounts of capitalized exploratory well costs pending determination of proved reserves was as follows:

Capitalized Costs	June 30, 2013		December 31, 2012
Property (acreage)
Unproved		30,322		-
Total property costs		30,322		-
Producing assets		9,107,001		-
Incomplete construction		-		-
Total capitalized		-		-
Accumulated depreciation and depletion		-		-
Net capitalized costs		9,137,323		-

The aging of amounts of capitalized well costs and number of projects are as follows:

Period Ending December 31	Well Costs Capitalized for the Period			Number of Projects
2008		5,536,873		1
2009		2,986,906		1
2010		3,544,207		1
2011		5,285,613		1
2012		965,360		1
June 30, 2013		517,880		1
Redemption by Prestige O & G, LLC		(9,699,517	)
Total		9,137,323

10. Subsequent Events

In the second quarter of 2013, the Company converted its Notes Receivable, Accounts Payable, and the divestment of its interest in E & P the Company in exchange for an interest in the Project Under Development.

Clay Thomas, P.C.

Certified Public Accountant

P.O. Box 311195

Houston, Texas 77231

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of Prestige O & G, LLC

I have audited the accompanying Statement of Financial Position of Prestige O & G, LLC as of December 31, 2012 and 2011, and the related Statements of Operations, Changes of Members’ Equity and Cash Flows for each of the two years ending December 31, 2012. Prestige O& G, LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on my audits.

In my opinion, the financial statements referred to above present fairly, in all material respects, the Statement of Financial Position of Prestige O & G, LLC as of December 31, 2012 and 2011, and the results of its Statements of Operations, Changes in Members’ Equity and its Cash Flows for each of the two years ending December 31, 2012 in conformity with accounting principles generally accepted in the United States of America.

Houston, Texas

February 12, 2013

Prestige O & G, LLC

Statement of Financial Position

For the Years Ending December 31, 2012 and 2011

	2012		2011
ASSETS
Current Assets
Cash and Cash Equivalents		5,338		5,338
Total Current Assets		5,338		5,338

Other Current Assets
Notes Receivable - Related Party		4,537,500		4,220,233
Prepaid Expense		1,309		1,000
Total Other Current Assets		4,538,809		4,221,233

Total Current Assets		4,544,147		4,226,571

Investments		5,369,633		5,637,257

TOTAL ASSETS		9,913,780		9,863,828

LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable - Related Party		189,726		168,792
Accounts Payable		5,900		5,900
Total Current Liabilities		195,626		174,692

Total Liabilities		195,626		174,692

Equity
Members' Capital Accounts		9,058,789		9,058,789
Retained Earnings		659,365		630,347
Total Equity		9,718,154		9,689,136
TOTAL LIABILITIES & EQUITY		9,913,780		9,863,828

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Operations

For the Years Ending December 31, 2012 and 2011

	2012			2011

Revenues and other income
Sales		-			-
Total revenues and other income		-			-

Operating Expenses
General and Administrative Costs
Legal		-			988
Miscellaneous		250			250
Professional Fees		5,900			7,451
Rent		14,475			12,000
Travel		-			862
Total General and Administrative Cost		20,625			21,551
Total Operating Expenses		20,625			21,551

Operating income (loss)		(20,625	)		(21,551	)

Other Income
Interest		317,267			386,085
Total other income		317,267			386,085

Net Income		296,642			364,534

Comprehensive Income Statement

Other comprehensive income (loss)
Net unrealized gains (losses) on investments		(267,624	)		(328,395	)
Comprehensive income		29,018			36,139

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Cash Flows

For the Years Ending December 31, 2012 and 2011

	2012			2011

Operating Activities
Net Income		29,018			36,139
Adjustments to reconcile Net Income
to net cash provided by operations:
Accounts Payable		20,934			23,053
Accrued Expense		-			(1,500	)
Accrued Interest Income		95,233			(11,087	)
Notes Receivable		(412,500	)		(375,000	)
Prepaid Expense		(309	)		-
Net cash provided / (used) by Operating Activities		(267,624	)		(328,395	)

Investing Activities
Investment in E & P Co. LLC		267,624			328,395
Net cash provided / (used) by investing activities:		267,624			328,395

Financing Activities
Investment from Members		-			-
Net cash provided by Financing Activities		-			-
Net cash increase for period		-			-
Cash at Beginning of Period		5,338			5,338
Cash at end of period		5,338			5,338

Supplemental Disclosures

Cash paid during the year for:
Interest (net of amount capitalized)		-			-
Income Taxes		-			-

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Members' Equity

For the Year Ending December 31, 2011

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance January 1, 2010		9,058,789		968,075			10,026,864

Net Income / (loss)		-		(373,867	)		(373,867	)

Balance December 31, 2010		9,058,789		594,208			9,652,997

Member Investment		-		-			-

Net Income / (loss)		-		36,139			36,139

Balance December 31, 2011		9,058,789		630,347			9,689,136

Net Income / (loss)		-		29,018			29,018

Balance December 31, 2012		9,058,789		659,365			9,718,154

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of Prestige O& G, LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

Summary of Accounting Policies

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Accounting Changes

The Company did not adopt authoritative guidance in 2012 that had a material impact on the Company’s financial statements.

Cash Flow Information

Related Party Transactions

Summarized transactions involving related parties at year end 2012 and 2011 are shown in the table below:

Notes Receivable

	2012		2011
Balance at January 1		4,220,233		3,835,146
E & P Co., LLC		317,267		386,087
Total		4,537,500		4,220,233

Accounts Payable

	2012		2011
Balance at January 1		168,792		145,741
E & P Co., LLC		20,934		23,051
Total		189,726		168,792

Investments, Advances and Long-Term Receivables

The Company’s balance of investment in E & P Co., LLC held at year end 2012 and 2011 was $5,369,633 and $5,637,257, respectively.

Income, Sales-Based and Other Taxes

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

Subsequent Events

None noted.

Clay Thomas, P.C.

Certified Public Accountant

8302 Hausman Road

No. 518

San Antonio, Texas 78249

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and
Members of Prestige O & G, LLC

I have audited the accompanying Statement of Financial Position of Prestige O & G, LLC as of December 31, 2011 and 2010, and the related Statements of Operations, Changes of Members’ Equity and Cash Flows for each of the two years ending December 31, 2011. Prestige O& G, LLC’s management is responsible for these financial statements. My responsibility is to express an opinion on these financial statements based on my audits.

In my opinion, the financial statements referred to above present fairly, in all material respects, the Statement of Financial Position of Prestige O & G, LLC as of December 31, 2011 and 2010, and the results of its Statements of Operations, Changes in Members’ Equity and its Cash Flows for each of the two years ending December 31, 2011 in conformity with accounting principles generally accepted in the United States of America.

San Antonio, Texas

April 16, 2012

Prestige O & G, LLC

Statement of Financial Position

For the Years Ending December 31, 2011 and 2010

	2011		2010
ASSETS
Current Assets
Cash and Cash Equivalents		5,338		5,338
Total Current Assets		5,338		5,338

Other Current Assets
Notes Receivable - Related Party		4,220,233		3,834,146
Prepaid Expense		1,000		1,000
Total Other Current Assets		4,221,233		3,835,146

Total Current Assets		4,226,571		3,840,484

Investments		5,637,257		5,965,654

TOTAL ASSETS		9,863,828		9,806,138

LIABILITIES & EQUITY
Liabilities
Current Liabilities
Accounts Payable		5,900		7,400
Accounts Payable - Related Party		168,792		145,741
Total Current Liabilities		174,692		153,141

Total Liabilities		174,692		153,141

Equity
Members' Capital Accounts		9,058,789		9,058,789
Retained Earnings		630,347		594,208
Total Equity		9,689,136		9,652,997
TOTAL LIABILITIES & EQUITY		9,863,828		9,806,138

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Operations

For the Years Ending December 31, 2011 and 2010

	2011			2010

Revenues and other income
Sales		-			-
Total revenues and other income		-			-

Operating Expenses
General and Administrative Costs
Legal		988			15
Miscellaneous		250			-
Professional Fees		7,451			8,624
Rent		12,000			12,000
Travel		862			-
Total General and Administrative Cost		21,551			20,639
Total Operating Expenses		21,551			20,639

Operating income (loss)		(21,551	)		(20,639	)

Other Income
Interest		386,085			84,146
Total other income		386,085			84,146

Net Income		364,534			63,507

Comprehensive Income Statement

Other comprehensive income (loss)
Net unrealized gains (losses) on investments	(328,395	)	(437,374	)
Comprehensive income	36,139		(373,867	)

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Cash Flows

For the Years Ending December 31, 2011 and 2010

	2011			2010

Operating Activities
Net Income		36,139			(373,867	)
Adjustments to reconcile Net Income to net cash provided by operations:
Accounts Payable		23,053			18,239
Accrued Expense		(1,500	)		2,400
Accrued Interest Income		(11,087	)		(84,146	)
Notes Receivable		(375,000	)		(3,000,000	)
Net cash provided / (used) by Operating Activities		(328,395	)		(3,437,374	)

Investing Activities
Investment in E & P Co. LLC		328,395			437,374
Net cash provided / (used) by investing activities:		328,395			437,374

Financing Activities
Investment from Members		-			3,000,000
Net cash provided by Financing Activities		-			3,000,000
Net cash increase for period		-			-
Cash at Beginning of Period		5,338			5,338
Cash at end of period		5,338			5,338

Supplemental Disclosures

Cash paid during the year for:
Interest (net of amount capitalized)		-			-
Income Taxes		-			-

See accompanying notes to the financial statements.

Prestige O & G, LLC

Statement of Members' Equity

For the Year Ending December 31, 2011

	Members' Capital		Accumulated Earnings			Total Members' Equity

Balance January 1, 2010		9,058,789		968,075			10,026,864

Net Income / (loss)		-		(373,867	)		(373,867	)

Balance December 31, 2010		9,058,789		594,208			9,652,997

Member Investment		-		-			-

Net Income / (loss)		-		36,139			36,139

Balance December 31, 2011		9,058,789		630,347			9,689,136

See accompanying notes to the financial statements.

Notes to Financial Statements

The accompanying financial statements and the supporting and supplemental material are the responsibility of the management of Prestige O& G, LLC.

The Company’s principal business is energy, involving exploration, production, transportation and sale of crude oil and natural gas.

1. Summary of Accounting Policies

Purchase and sales of inventory with the same counterparty that are entered in to contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

Sales-Based Taxes. The Company reports sales and excise taxes on sales transactions on a gross basis of the Statement of Income (included in both revenues and costs).

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

2. Accounting Changes

The Company did not adopt authoritative guidance in 2011 that had a material impact on the Company’s financial statements.

3. Cash Flow Information

4. Related Party Transactions

Summarized transactions involving related parties at year end 2011 and 2010 are shown in the table below:

Notes Receivable

	2011		2010
Balance at January 1		3,835,146		750,000
E & P Co., LLC		386,087		3,084,146
Total		4,220,233		3,835,146

Accounts Payable

	2011		2010
Balance at January 1		145,741		127,501
E & P Co., LLC		23,051		18,240
Total		168,792		145,741

5. Investments, Advances and Long-Term Receivables

The Company’s balance of investment in E & P Co., LLC held at year end 2011 and 2010 was $5,637,257 and $5,965,654, respectively.

6. Income, Sales-Based and Other Taxes

The Company has not been subjected to severance tax for sales of gas from its Louisiana project. This severance tax is paid by the buyer and withheld from the settlement amount on the sale.

7. Subsequent Events

None noted.

Woodgate Energy Corporation Development Stage Company Statement of Financial Position
	30-Sep-13		31-Dec-12
ASSETS

Current Assets
Cash and Cash Equivalents		1,044,270		2,000.00
Accounts Receivable		337,481		-
Accrued Gas Sales		715		-
Prepaid Expense		12,500		-
Refundable Deposits		11,204		-
		1,406,170		2,000.00

Fixed Assets
Property and Equipment		33,403		-
Furniture and Fixtures		39,236		-
Project Under Development		19,282,703		-
Intangibles		8,157,352		-
Less accumulated DD&A		69,276		-
Total Assets		28,849,588		2,000.00

LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts Payable		599,654		-
Accrued Expense		366,084		350.00
Payroll Tax Liabilities		4,817		-
Direct Deposit Liabilities		13,553		-
Notes Payable		452,655		-
		1,436,763		350.00

Long-term Debt
Notes Payable		-		-
Total		1,436,763		350.00
Equity

Common Stock (100,000,000 Common Shares and 20,000,000 Preference shares Authorized. 47,295,000 Common shares and 20,000,000 Common shares issued at par value (0.0001) and outstanding as of Sept 30, 2013 and Dec 31, 2012 respectively)		4,730		2,000.00
Additional Paid-in Capital		27,408,095		(350.00	)
Total Equity		27,412,825		1,650.00
Total Liabilities and Stockholders' Equity		28,849,588		2,000.00

Woodgate Energy Corporation Development Stage Company Statement of Operations
							July 23, 2012 (Inception) to Sep
	30-Sep-13			31-Dec-12			30, 2013

Revenues
Gas Sales		2,968			-			2,968
Total		2,968			-			2,968
Costs and Expenses
Direct operating costs		2,951			-			2,951
General and administrative costs
Bad Debt		107,302			-			107,302
Adv. & Marketing Expenses		820			-			820
Bank charges		539			-			539
Communication		423			-			423
Depreciation, depletion and amortization		(470	)		-			(470	)
Employee insurance		6,862			-			6,862
Insurance		16,813			-			16,813
Legal		294			-			294
License Fees		378			-			378
Miscellaneous		1,319			1357			2,676
Office equipment		2,455			-			2,455
Payroll		341,407			-			341,407
Professional Fees		454,303			-			454,303
Rent		36,791			-			36,791
Stationery		2,146			-			2,146
Taxes		4,028			-			4,028
Travel		33,600			-			33,600
Utilities		2,840			-			2,840
Total		1,011,850			1,357			1,013,207
Operating Income		(1,011,833	)		(1,357	)		(1,013,190	)

Interest, Expense and Other Income
Other Income		163,127			-			163,127
Net unrealized gains (losses) on investments		(271,317	)		-			(271,317	)
Income from Continuing Operations		(1,120,023	)		(1,357	)		(1,121,380	)

Earnings per share		(0.06	)		0.00			(0.06	)

Woodgate Energy Corporation Development Stage Company Statement of Cash Flows
	30-Sep-13			31-Dec-12			July 23, 2012 (Inception) to Sep 30, 2013
Operating Activities
Net Income		(1,120,023	)		(1,357	)		(1,121,380	)
Adjustments to reconcile Net Income to net Cash provided by Operations
Accounts Payable		(280,408	)		-			(280,408	)
Accounts Receivable		702,869			-			702,869
Accrued Sale of Gas Income		218			-			218
Prepaid Expense		1,309			-			1,309
Credit Cards		200			-			200
Depreciation		(470	)		-			(470	)
Direct Deposit Liabilities		13,553			-			13,553
Payroll Tax Liabilities		(3,457	)		-			(3,457	)
Accrued Expense		233,272			350			233,622
Net Cash Provided/(used) by Operating Activities		(452,937	)		(1,007	)		(453,944	)

Investing Activities
Intangible Assets		(8,157,352	)		-			(8,157,352	)
Projects Under Development		(613,743	)		-			(613,743	)
Investment in EPCO		18,960,845			-			18,960,845
Debt Support to EPCO		(289,119	)		-			(289,119	)
		9,900,631			0			9,900,631
Financing Activities
Cash Balances from Subsidiaries		53,100			-			53,100
Notes Payables		(13,199,772	)		-			(13,199,772	)
Proceeds from Issuance of Stock		1,293,066			2,000			1,295,066
Proceeds from Stock Sale		875			-			875
Proceeds from Members/Stockholder's Contribution		3,447,307			1,007			3,446,314
Net Cash Provided by Financing Activities		(8,405,424	)		3,007			(8,404,417	)

Net Cash increase for period		1,042,270			2,000			1,042,270
Cash at Beginning of Period		2,000			0			2,000
Cash at end of Period		1,044,270			2,000			1,044,270

	Woodgate Energy Corporation Development Stage Company Statement of Stockholders' Equity For the period ending Sep 30, 2013
	Shares			Members' Capital			Additional Paid-in Capital		Accumulated Earnings			Total Members Equity
Balance July 23, 2012 Inception		0			0			0		0			0

Issuance of Common Stock		20,000,000			2,000								2,000

Additional Paid-in-Capital		0			0			1,007		0			1,007

Net Income/loss		0			0			0		(1,357	)		(1,357	)

Balance December 31, 2012		20,000,000			2,000			1,007		(1,357	)		1,650

Redemption of Common Stock		(10,750,000	)		(1,075	)		0		0			(1,075	)

Issuance of Common Stock		38,045,000			3,805			28,528,469		0			28,532,273

Net Income/loss		0			0			0		(1,120,023	)		(1,120,023	)

Balance September 30, 2013		47,295,000			4,730			28,529,476		(1,121,380	)		27,412,825

WOODGATE ENERGY CORPORATION

UNAUDITED PRO FORMA CONDENSED COMBINED BALANCE SHEET

AS OF SEPTEMBER 30, 2013

	Woodgate		E & P Co		Prestige O & G		Pro Forma Adjustments			Pro Forma Combined

ASSETS

Current Assets
Cash and Cash Equivalents		1,000,611		40,833		2,826		-			1,044,270
Accounts Receivable		289,119		47,931		431		(337,481	)e		0
Accrued Gas Sales		-		715		-		-			715
Prepaid Expense		-		12,500		-		-			12,500
Refundable Deposits		-		11,204		-		-			11,204
		1,289,730		113,183		3,257		(337,481	)		1,068,689

Fixed Assets
Property and Equipment		-		33,403		-		-			33,403
Furniture and Fixtures		-		39,236		-		-			39,236
Project Under Development		-		9,185,255		10,097,448		112,504	c		19,395,207
Intangibles		-		8,157,352		-		-			8,157,352
Less accumulated DD&A		-		69,276		-		-			69,276
Total Assets		1,289,730		17,459,153		10,100,705		(224,977	)		28,624,611

LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts Payable		872		550,851		47,931		(337,481	)e		262,173
Accrued Expense		-		364,084		2,000		-			366,084
Payroll Tax Liabilities		-		4,817		-		-			4,817
Direct Deposit Liabilities		-		13,553		-		-			13,553
Notes Payable		-		452,655		-		-			452,655
		872		1,385,960		49,931		(337,481	)		1,099,282

Long-term Debt
Notes Payable		-		-		-		-			-
Total		872		1,385,960		49,931		(337,481	)		1,099,282
Stockholder's Equity		1,288,858		16,073,193		10,050,774		112,504	d		27,525,329
Total Liabilities and Stockholders' Equity		1,289,730		17,459,153		10,100,705		(224,977	)		28,624,611

WOODGATE ENERGY CORPORATION

UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF OPERATIONS

AS OF SEPTEMBER 30, 2013

	Woodgate			E & P Co			Prestige O & G			Pro Forma Adjustments			Pro Forma Combined

Revenues
Gas Sales		-			2,537			431			-			2,968
Total		-			2,537			431			-			2,968
Costs and Expenses
Direct operating costs		-			2,951			-			-			2,951
General and administrative costs
Bad Debt		-			107,302			-			-			107,302
Adv. & Marketing Expenses		325			495			-			-			820
Bank charges		-			527			12			-			539
Communication		-			423			-			-			423
Depreciation, depletion and amortization		-			(470	)		-			-			(470	)
Employee insurance		-			6,862			-			-			6,862
Insurance		-			16,813			-			-			16,813
Legal		294			-			-			-			294
License Fees		-			378			-			-			378
Miscellaneous		973			346			-			-			1,319
Office equipment		-			2,455			-			-			2,455
Payroll		-			341,407			-			-			341,407
Professional Fees		8,578			441,225			4,500			-			454,303
Rent		-			31,554			5,237			-			36,791
Stationery		-			2,146			-			-			2,146
Taxes		-			4,028			-			-			4,028
Travel		-			33,600			-			-			33,600
Utilities		-			2,840			-			-			2,840
Total		10,170			991,931			9,749			-			1,011,850
Operating Income		(10,170	)		(992,345	)		(9,318	)		-			(1,011,833	)

Interest, Expense and Other Income
Other Income		2,286			2,028			158,813			(158,813	)a		4,314
Net unrealized gains (losses) on investments		-			-			(271,317	)		271,317	b		-
Income from Continuing Operations		(7,884	)		(990,317	)		(121,822	)		112,504			(1,007,519	)

WOODGATE ENERGY CORPORATION

NOTES TO UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS

AS OF SEP 30, 2013

On September 25, 2013, WoodGate Energy Corporation, a Delaware corporation (the “Company”), entered into a reverse acquisition business combination with two entities in a combined stock-for-stock transaction. E & P Co., LLC, the acquirer, acquired and caused to be issued 26,634,230 shares of common stock in the Company in exchange for the acquirer’s membership units. Prestige O & G, LLC, acquired and caused to be issued 10,115,770 shares of common stock in the Company in exchange for its membership units.

In accordance with ASC 805-10-55-12, E & P Co., LLC is defined as the “acquirer” in the combination due to the following pertinent facts and circumstances:

The proposal for the transaction was initiated by E & P Co., LLC.

The relative voting rights indicate E & P Co., LLC receies the largest portion of the shareholder holding and comparative voting rights in the combined entity are as follows:

Shareholders	Shares		Percentage
Original WoodGate shareholders		500,000		1.34	%
E & P Co., LLC		26,634,230		71.50	%
Prestige O & G, LLC		10,115,770		27.16	%
Total		37,250,000		100.00	%

The acquirers have the ability to elect or appoint or to remove a majority of the members of the governing body of the combined entity. Prior to combination, all members of the previous governing body resigned and have not been reappointed.

The former management of E & P Co., LLC dominates the management of the combined entity.

The size of E & P Co., LLC is significantly larger than the Company or Prestige O & G, LLC.

The pro forma financial information shall represent results for the period ending September 30, 2013 for the entities presented.

Eliminations to the Pro Forma Financial Statements

Pro Forma Income Statement Adjustments

(a)

Elimination of interest earned on loans extended to E & P Co., LLC.

(b)

Elimination of loss resulting from investment in E & P Co., LLC.

Pro Forma Balance Sheet Adjustments

(c)

To eliminate the capitalization of interest in accordance to successful efforts treatment.

(d)

To eliminate Prestige O & G, LLC’s investment in E & P Co., LLC.

(e)

To eliminate inter-company receivables for Woodgate Energy Corporation, E & P Co., LLC and Prestige O&G, LLC.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunder duly authorized.

	WOODGATE ENERGY CORPORATION

Date: February 11, 2014	/s/ Fuad Al-Humoud
	President

EX-2.1 2 v367661_ex2-1.htm EXHIBIT 2.1

EXCHANGE AGREEMENT

EXCHANGE AGREEMENT (“Agreement”) dated as of the 6^th Day of September 2013 (the "Effective Date") by and among WoodGate Energy Corporation, a Delaware corporation (“Parent"), E & P CO, LLC, a Texas limited liability company ("Company"), and each of the Members of the Company, all of whom are listed on Schedule A hereto (each, a Member and, together the "Members"). Each of Parent, Company, and each of the Members may, sometimes herein, be referred to as a "Party" and, together, the "Parties").

BACKGROUND

Each of the Members of the Company desires to exchange each, and all, of the Member Units (each a "Unit" and, together, "Units" ) such Member owns in the Company (as set-forth in Schedule A) for a specific number of shares of voting common stock, par value $0.0001 per share, of Parent (the “Parent Shares”) as set-forth in Schedule A, on the terms and subject to the conditions set forth herein (the “Exchange”).

In consideration of the mutual covenants and agreements contained in this Agreement, the receipt and sufficiency of which are hereby acknowledged, and intending to be legally bound, the Parties hereby agree as follows:

ARTICLE I

THE COMPANY UNITS AND THE PARENT SHARES

Section 1.1 The Units. The Units shall be exchanged for Parent Shares and the Parent Shares shall be exchanged for the Units held by each of the Members in number as set-forth in schedule A, pursuant to Article II hereof, which is intended to qualify as a Tax-Free Acquisition under Section 368(a)(1)(B) of the Internal Revenue Code (together, the "Exchange").

ARTICLE II

EXCHANGE COMPANY MEMBER UNITS FOR PARENT COMMON SHARES

Section 2.1 Merged Assets. The unaudited financial statements of the Company as of the 31^st August 2013 show total Capitalization, (“Merged Assets”) in the aggregate of $6,699,813.

Section 2.2 Exchange for Merged Assets. At the Exchange Closing and upon the terms and subject to the conditions of this Agreement, each of the Members agrees to exchange all of such Member's Units for the designated number of Parent Common Shares as set forth in schedule A, all of which are authorized and which will be issued by Parent. Such exchange will be executed based on 10,000 Parent Common Shares for each Member Unit of the Company.

Section 2.3 Company Debt. As of 31^st August 2013, the Company's unaudited financial statements show outstanding debt to various creditors, (“Creditors” and each “Creditor”) totaling $9,440,835.

Section 2.4 Exchange for Company Debt. At the Exchange Closing and upon the terms and subject to the conditions of this Agreement, each of the Creditors of the Company agrees to transfer its outstanding loans receivable from the Company in exchange for a proportionate equity in the Parent in the form of Parent Common Shares. Parent shall issue to each such Creditor the designated number of Common Shares as set forth in Schedule A. Such Exchange will be based on one Common Share for each $0.71 of Debt as of 31^st August 2013.

Section 2.5 Exchange Closing.

(a) Each Member will deliver a certificate, endorsed for transfer to Parent, representing the Units being exchanged and, and Parent will deliver a certificate, endorsed for transfer to each Member, representing the Parent Shares being exchanged in the number set forth in Section 1.1 hereof. Subject to the satisfaction of the conditions set forth in Article VII, the time and date of such deliveries shall be 10:00 a.m., Houston time, on a date and at a place to be specified by the Parties (the “Exchange Closing”), which date shall be no later than the day after satisfaction or waiver of the latest to occur of the conditions set forth in Article VII, as evidenced by, and specified in, a Notice signed by each of the Parties.

(b) The documents to be delivered at the Exchange Closing by or on behalf of the Parties hereto pursuant to this Article II and any additional documents reasonably requested by either Party pursuant to Section 6.2, will be delivered at the Exchange Closing at the address of the offices of Company set forth in Section 8.1.

ARTICLE III

REPRESENTATIONS AND WARRANTIES OF THE COMPANY

The Company represents and warrants to Parent as of the date hereof that:

Section 3.1 Existence and Power. The Company is a limited liability company duly formed and validly existing under, and in compliance with, the laws of the State of Texas. The Company has the requisite corporate power and authority to own or lease all of its properties and assets and to carry on its business as it is now being conducted, and is duly licensed or qualified to do business in each jurisdiction in which the nature of the business conducted by it or the character or location of the properties and assets owned or leased by it makes such licensing or qualification necessary.

Section 3.2 Business. On October 2, 2006, E&Pco, LLC entered into an Exploration Agreement With Coalbed Methane Lease Option East (“IP Agreement”) with International Paper Company, a New York corporation (“IP”) granting rights to explore for, and otherwise evaluate, deposits of coal containing coal bed methane (“CBM”) in certain areas in Caldwell Parish, Louisiana comprising approximately Nine Thousand Six Hundred and Sixty-One (9,661) acres (the “Option Area”) as more particularly described in the Lease, attached hereto, for the purpose of determining whether to exercise the lease option (“Lease Option”) granted in the IP Agreement and proceed with development and production in the Option Area (the “Project’); Further, E&Pco LLC did exercise the Lease Option and entered into and executed that certain Coalbed Methane Lease dated the 1st day of May 2008. Further E&P CO. LLC is making regular annual renewals of such lease as deem currently legally valid right to the project and development thereof and clear from any third party rights and liens; Further E&P LLC entered into a Participation Agreement on 25^th June 2013 with Prestige O&G, LLC to regulate their partnership in Project where each hold 50% interest in the Project.

Section 3.3 Capitalization. The Company, as a Texas limited liability company, does not have common stock, or any other type or class of stock; instead, Texas law authorizes limited liability companies to issue "Member Units". The Company had 1,333.7280 Member Units issued and outstanding as of September 6, 2013 (the “Company Capitalization Date”)

As of the Company Capitalization Date, the Company had no authorized or outstanding Options to purchase Units or any other type of instrument, program, plan or agreement entitling anyone to acquire Units or any other equity interest, in whole or part. All of the issued and outstanding Member Units have been duly authorized and validly issued and are fully paid, non-assessable and free of preemptive rights, with no personal liability attaching to the ownership thereof.

Section 3.4 Authorization. The execution, delivery and performance of this Agreement has been duly authorized by all necessary action on the part of the Company and each of the Members requiring such authorization, and this Agreement is a valid and binding obligation of the Company and each of the Members, enforceable against each of them in accordance with its terms.

Section 3.5 Board Approval. The transactions contemplated by this Agreement, including without limitation the issuance of the Units and the compliance with the terms of this Agreement, have been unanimously adopted, approved, and declared advisable unanimously by the Board of Managers of the Company.

Section 3.6 Non-Contravention. The execution, delivery and performance of this Agreement, and the consummation by the Company of the transactions contemplated hereby, will not conflict with, violate, or result in a breach of any provision of, or constitute a default (or an event which, with notice or lapse of time or both would constitute a default) under, or result in the termination of or accelerate the performance required by, or result in a right of termination or acceleration under, any provision of the Certificate of Formation, Operating Agreement, or other governing instrument of the Company.

Section 3.7 Exchange for Own Account. Each of the Members of the Company is acquiring the Parent Shares for its own account and not with a view to the distribution thereof in violation of the Securities Act of 1933, as amended, and the rules and regulations of the Securities and Exchange Commission (the “SEC”) promulgated thereunder (the “Securities Act”).

Section 3.8 Private Placement. The Company understands that (i) the Parent Shares have not been registered under the Securities Act or any state securities laws, by reason of their issuance by Parent in a transaction exempt from the registration requirements thereof and (ii) the Parent Shares may not be sold unless such disposition is registered under the Securities Act and applicable state securities laws or is exempt from registration thereunder. Parent may issue new shares - Common or Preferred - in compliance with its plans to meet the minimum capitalization to meet its strategic and business plans. The Parties have the right to subscribe in any offerings of new shares as complaint with terms set forth for each offering. Likewise, Parties may decide not to participate in any of such future offerings which may result in a dilution of its interest in the Parent.

Section 3.9 Legend. Each certificate representing an Exchange Share will bear a legend to the following effect unless Parent determines otherwise in compliance with applicable law:

“THE SHARES REPRESENTED BY THIS CERTIFICATE HAVE NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR THE SECURITIES LAWS OF ANY STATE OR OTHER JURISDICTION. THE SHARES HAVE BEEN ACQUIRED FOR INVESTMENT AND NEITHER THIS SHARE NOR ANY INTEREST OR PARTICIPATION HEREIN MAY BE REOFFERED, SOLD, ASSIGNED, TRANSFERRED, PLEDGED, ENCUMBERED OR OTHERWISE DISPOSED OF IN THE ABSENCE OF SUCH REGISTRATION OR UNLESS SUCH TRANSACTION IS EXEMPT FROM, OR NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT.”

ARTICLE IV

REPRESENTATIONS AND WARRANTIES OF PARENT

Parent represents and warrants to the Company as of the date hereof that:

Section 4.1 Existence and Power. Parent is duly organized and validly existing under the laws of the state of its organization and has all requisite power and authority to enter into and perform its obligations under this Agreement.

Section 4.2 Authorization. The execution, delivery and performance of this Agreement has been duly authorized by all necessary action on the part of Parent, and this Agreement is a valid and binding obligation of Parent, enforceable against it in accordance with its terms.

Section 4.3 Valid Issuance. For the purpose of this Exchange, Parent shall issue 13,337,280 Common Shares to be allocated for the Members for Merged Assets in accordance with this Agreement and as set forth in Schedule A. In addition, Parent shall issue 13,296,950 Common Shares to be allocated for the Creditors of the Company (“Creditors Issue”) in accordance with this Agreement and as set forth in Schedule A. The Parent Shares have been duly authorized by all necessary corporate action. When issued and sold against receipt of the consideration therefor, the Parent Shares will be validly issued, fully paid and non-assessable, will not subject the holders thereof to personal liability and will not be issued in violation of preemptive rights.

Section 4.4 Non-Contravention. The execution, delivery and performance of this Agreement will not conflict with, violate or result in a breach of any provision of, or constitute a default (or an event which, with notice or lapse of time or both would constitute a default) under, or result in the termination of or accelerate the performance required by, or result in a right of termination or acceleration under, any provision of the organizational or governing documents of Parent.

Section 4.5 Exchange for Own Account. Parent is acquiring the Units for its own account and not with a view to the distribution thereof in violation of the Securities Act.

Section 4.6 Exempt Transaction; No Transfer. Parent understands that (i) the Units have not been registered under the Securities Act or any state securities laws, by reason of their issuance by the Company in a transaction exempt from the registration requirements thereof and (ii) the Units may not be sold unless such disposition is registered under the Securities Act and applicable state securities laws or is exempt from registration thereunder.

Section 4.7 Legend. Each certificate representing a Parent Shares will bear a legend to the following effect unless the Company determines otherwise in compliance with applicable law:

“THE SHARES REPRESENTED BY THIS CERTIFICATE HAVE NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR THE SECURITIES LAWS OF ANY STATE OR OTHER JURISDICTION. THE UNITS HAVE BEEN ACQUIRED FOR INVESTMENT AND NEITHER THE SHARES REPRESENTED BY THIS CERTIFICATE NOR ANY INTEREST OR PARTICIPATION HEREIN MAY BE REOFFERED, SOLD, ASSIGNED, TRANSFERRED, PLEDGED, ENCUMBERED,S OR OTHERWISE DISPOSED OF IN THE ABSENCE OF SUCH REGISTRATION OR UNLESS SUCH TRANSACTION IS EXEMPT FROM, OR NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT.”

ARTICLE V

CONDITIONS TO EXCHANGE CLOSING

Section 5.1 Conditions to Each Party’s Obligation to Effect the Exchange. The respective obligations of the Parties hereunder to effect the Exchange shall be subject to the condition that no order, injunction or decree issued by any court or agency of competent jurisdiction or other law preventing or making illegal the consummation of the Exchange shall be in effect.

ARTICLE VI

MISCELLANEOUS

Section 6.1 Notices. All notices, requests, demands, claims and other communications that are required to be, or which may be, given by either Party (“Notifying Party”) under this Agreement (each, a “Notice”) shall be in writing addressed to the other Party (“Intended Recipient”), at the relevant Intended Recipient’s address set forth below. Any Notice shall be (i) delivered in person or by same day or overnight courier, (ii) sent by electronic facsimile or E-mail transmission, or (iii) mailed, certified first class mail, postage prepaid, return receipt requested, to the Intended Recipient as follows:

If to Parent:		If to Company:

WOODGATE ENERGY CORPORATION		E & P CO, LLC

2500 Tanglewilde St., Ste. 260		2500 Tanglewilde St., Ste. 260
Houston, TX 77063		Houston, TX 77063
Tel: 713-978-6551		Tel: 713-978-6551
E-mail: okaldirimj@e-pco.com		E-mail: okaldirimj@e-pco.com
FAX: 713-978-6772		FAX: 713-978-6772

By Notice given in accordance with this Section, either Party may provide, at any time, a different address for notice under this Section.

A Notice shall be effective (“Notice Effective Date”) (i) if delivered in person or by courier, upon actual receipt by the Intended Recipient, (ii) if sent by electronic facsimile or email transmission, when the Notifying Party receives facsimile or email confirmation that such notice was received at the facsimile number or email address, as the case may be, of the Intended Recipient, or (iii) if mailed, upon the earlier of five (5) business days after deposit in the mail or the date of delivery as shown by the return receipt therefor.

Section 6.2 Further Assurances. Each Party hereto shall do and perform or cause to be done and performed all further acts and shall execute and deliver all other agreements, certificates, instruments and documents as any other Party hereto reasonably may request in order to carry out the intent and accomplish the purposes of this Agreement and the consummation of the transactions contemplated hereby.

Section 6.3 Amendments and Waivers. Any provision of this Agreement may be amended or waived if, but only if, such amendment or waiver is in writing and is duly executed and delivered by the Company and Parent. No failure or delay by any Party in exercising any right, power or privilege hereunder shall operate as a waiver thereof nor shall any single or partial exercise thereof preclude any other or further exercise thereof or the exercise of any other right, power or privilege. The rights and remedies herein provided shall be cumulative and not exclusive of any rights or remedies provided by law.

Section 6.4 Fees and Expenses. Each Party hereto shall pay all of its own fees and expenses (including attorneys’ fees) incurred in connection with this Agreement and the transactions contemplated hereby.

Section 6.5 Successors and Assigns. The provisions of this Agreement shall be binding upon and inure to the benefit of the Parties hereto and their respective successors and assigns, provided that neither Party may assign, delegate or otherwise transfer any of its rights or obligations under this Agreement without the consent of the other Party hereto.

Section 6.6 Governing Law. This Agreement shall be governed and construed in accordance with the internal laws of the State of Texas applicable to contracts made and wholly performed within such state, without regard to any applicable conflicts of law principles. The Parties hereto agree that any suit, action or proceeding brought by either Party to enforce any provision of, or based on any matter arising out of or in connection with, this Agreement or the transactions contemplated hereby shall be brought in any federal or state court located in the State of Texas. Each of the Parties hereto submits to the jurisdiction of any such court in any suit, action or proceeding seeking to enforce any provision of, or based on any matter arising out of, or in connection with, this Agreement or the transactions contemplated hereby and hereby irrevocably waives the benefit of jurisdiction derived from present or future domicile or otherwise in such action or proceeding. Each Party hereto irrevocably waives, to the fullest extent permitted by law, any objection that it may now or hereafter have to the laying of venue of any such suit, action, or proceeding in any such court or that any such suit, action or proceeding brought in any such court has been brought in an inconvenient forum.

Section 6.7 Waiver Of Jury Trial. EACH OF THE PARTIES HERETO HEREBY IRREVOCABLY WAIVES ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATED TO THIS AGREEMENT AND THE TRANSACTIONS CONTEMPLATED HEREBY.

Section 6.8 Entire Agreement. This Agreement constitutes the entire agreement between the Parties with respect to the subject matter of this Agreement and supersedes all prior agreements and understandings, both oral and written, between the Parties and/or their affiliates with respect to the subject matter of this Agreement.

Section 76.9 Severability. In the event any provision of this Agreement shall be held to be invalid, illegal, or unenforceable by final judgment of a court of competent jurisdiction, the validity, legality, and enforceability of the remaining provisions shall not in any way be affected or impair thereby, subject to the following provisions. In the event of any such judgment, the Parties shall cooperate in good faith to amend this Agreement in such manner as shall give effect thereto while preserving the existing benefit of its bargain for each of the Parties and minimizing disruption to, and the existing relationships, agreements, and arrangements of, each of them. However, no such amendment shall i) materially and adversely affect the economic relationship of the Parties; or, ii) cause either of the Parties to incur additional material obligations or liabilities. Such approval or disapproval by either of the Parties shall not be withheld, delayed, or conditioned unreasonably.

Section 6.10 Counterparts; Third Party Beneficiaries. This Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures were upon the same instrument. No provision of this Agreement shall confer upon any person other than the Parties hereto any rights or remedies hereunder.

Section 6.11 Specific Performance. The Parties agree that irreparable damage would occur in the event that any of the provisions of this Agreement were not performed in accordance with their specific terms. It is accordingly agreed that the Parties shall be entitled to seek specific performance of the terms hereof, this being in addition to any other remedies to which they are entitled at law or equity.

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IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to be duly executed by their respective authorized officers as of the Effective Date.

PARENT:

WOODGATE ENERGY CORPORATION

By	/s/ Fuad Alhumoud
	Fuad Alhumoud
Title:	Director

COMPANY:

E & P CO, LLC		Prestige O&G, LLC

By	/s/ Osman KaldirimJr.	By	/s/ Osman Kaldirim
	Osman KaldirimJr.		Osman Kaldirim
Title:	Vice President	Title:	Vice Chairman

Rasan Associates, LLC		Rasan Private Equity Inc.

By	/s/ Fuad Alhumoud	By	/s/ Abdulrahman AlKooheji
	Fuad Alhumoud		Abdulrahman AlKooheji
Title:	Manager	Title:	Director

Delta O&G, LLC		Caldwell US, Inc.

By	/s/ Osman Kaldirim	By	/s/ Abdulla Al-Faddagh
	Osman Kaldirim		Abdulla Al-Faddagh
Title:	Manager	Title:	Director

EPMD, LLC		Rasan Energy Company

By	/s/ Osman Kaldirim	By	/s/ Hamed Alhumoud
	Osman Kaldirim		Hamed Alhumoud
Title:	Chairman	Title:	Chairman

Univest, Inc.

By	/s/ Fuad Alhumoud
	Fuad Alhumoud
Title:	Director

SCHEDULE A

TABLE 1 – Allocation of Common Shares for Merged Assets

S. No.	Holder	Common Shares of Woodgate Energy to be Allocated to Members of EPCO
1	Caldwell US, Inc.		6,542,580
2	Rasan Associates, LLC		274,377
3	EPMD, LLC		5,057,885
4	Delta O&G, LLC		1,462,438
	TOTAL		13,337,280

TABLE 2 – Allocation of Common Shares against Debt

S. No.	Holder	No. of Debt Shares
1	Caldwell US, Inc		210,528
2	Rasan Associates, LLC		2,000,000
3	Rasan Private Equity Inc.		1,498,592
4	EPMD, LLC		8,578,827
5	Delta O&G, LLC		1,009,003
	TOTAL		13,296,950

EX-2.2 3 v367661_ex2-2.htm EXHIBIT 2.2

EXCHANGE AGREEMENT

EXCHANGE AGREEMENT (“Agreement”) dated as of the 6^th Day of September 2013 (the "Effective Date") by and among WoodGate Energy Corporation, a Delaware corporation (“Parent"), PRESTIGE O&G, LLC, a Texas limited liability company ("Company"), and each of the Members of the Company, all of whom are listed on Schedule A hereto (each, a Member and, together the "Members"). Each of Parent, Company, and each of the Members may, sometimes herein, be referred to as a "Party" and, together, the "Parties").

BACKGROUND

ARTICLE I

THE UNITS AND THE PARENT SHARES

ARTICLE II

EXCHANGE COMPANY MEMBER UNITS FOR PARENT COMMON SHARES

Section 2.1 Merged Assets. The unaudited financial statements of the Company as of the 31^st August 2013 show total Capitalization, (“Merged Assets”) in the aggregate of $10,054,855.

Section 2.3 Exchange Closing.

ARTICLE III

REPRESENTATIONS AND WARRANTIES OF THE COMPANY

The Company represents and warrants to Parent as of the date hereof that:

Section 3.2 Business. Prestige O&G, LLC entered into a Participation Agreement on 25^th June 2013 with E&P Co., LLC to regulate their partnership in Project where each holds 50% interest in the Project. On October 2, 2006, E&Pco, LLC entered into an Exploration Agreement With Coalbed Methane Lease Option East (“IP Agreement”) with International Paper Company, a New York corporation (“IP”) granting rights to explore for, and otherwise evaluate, deposits of coal containing coal bed methane (“CBM”) in certain areas in Caldwell Parish, Louisiana comprising approximately Nine Thousand Six Hundred and Sixty-One (9,661) acres (the “Option Area”) as more particularly described in the Lease, attached hereto, for the purpose of determining whether to exercise the lease option (“Lease Option”) granted in the IP Agreement and proceed with development and production in the Option Area (the “Project’); Further, E&Pco LLC did exercise the Lease Option and entered into and executed that certain Coalbed Methane Lease dated the 1st day of May 2008. Further E&P CO. LLC is making regular annual renewals of such lease as deem currently legally valid right to the project and development thereof and clear from any third party rights and liens.

Section 3.3 Capitalization. The Company, as a Texas limited liability company, does not have common stock, or any other type or class of stock; instead, Texas law authorizes limited liability companies to issue "Member Units". The Company had 1,011.5770 Member Units issued and outstanding as of September 6, 2013 (the “Company Capitalization Date”)

Section 3.9 Legend. Each certificate representing an Exchange Share will bear a legend to the following effect unless Parent determines otherwise in compliance with applicable law:

ARTICLE IV

REPRESENTATIONS AND WARRANTIES OF PARENT

Parent represents and warrants to the Company as of the date hereof that:

Section 4.3 Valid Issuance. For the purpose of this Exchange, Parent shall issue 10,115,770 Common Shares to be allocated for the Members for Merged Assets in accordance with this Agreement and as set forth in Schedule A. The Parent Shares have been duly authorized by all necessary corporate action. When issued and sold against receipt of the consideration therefore, the Parent Shares will be validly issued, fully paid and non-assessable, will not subject the holders thereof to personal liability and will not be issued in violation of preemptive rights.

Section 4.5 Exchange for Own Account. Parent is acquiring the Units for its own account and not with a view to the distribution thereof in violation of the Securities Act.

Section 4.7 Legend. Each certificate representing a Parent Shares will bear a legend to the following effect unless the Company determines otherwise in compliance with applicable law:

“THE SHARES REPRESENTED BY THIS CERTIFICATE HAVE NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR THE SECURITIES LAWS OF ANY STATE OR OTHER JURISDICTION. THE UNITS HAVE BEEN ACQUIRED FOR INVESTMENT AND NEITHER THE SHARES REPRESENTED BY THIS CERTIFICATE NOR ANY INTEREST OR PARTICIPATION HEREIN MAY BE REOFFERED, SOLD, ASSIGNED, TRANSFERRED, PLEDGED, ENCUMBERED,S OR OTHERWISE DISPOSED OF IN THE ABSENCE OF SUCH REGISTRATION OR UNLESS SUCH TRANSACTION IS EXEMPT FROM, OR NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT.”

ARTICLE V

CONDITIONS TO EXCHANGE CLOSING

ARTICLE VI

MISCELLANEOUS

If to Parent:	If to Company:

WOODGATE ENERGY CORPORATION	PRESTIGE O&G, LLC

2500 Tanglewilde St., Ste. 260	2500 Tanglewilde St., Ste. 260
Houston, TX 77063	Houston, TX 77063
Tel: 713-978-6551	Tel: 713-978-6551
E-mail: okaldirimj@e-pco.com	E-mail: okaldirimj@e-pco.com
FAX: 713-978-6772	FAX: 713-978-6772

By Notice given in accordance with this Section, either Party may provide, at any time, a different address for notice under this Section.

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IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to be duly executed by their respective authorized officers as of the Effective Date.

PARENT:

WOODGATE ENERGY CORPORATION

By	/s/ Fuad Alhumoud
	Fuad Alhumoud
Title:	Director

Caldwell US, Inc.

By	/s/ Abdulla Al-Faddagh
	Abdulla Al-Faddagh
Title:	Director

EPMD, LLC

By	/s/ Osman Kaldirim
	Osman Kaldirim
Title:	Chairman

Prestige O&G, LLC

By	/s/ Osman Kaldirim
	Osman Kaldirim
Title:	Vice Chairman

SCHEDULE A

TABLE 1 – Allocation of Common Shares for Merged Assets

S. No.	Holder	Common Shares of Woodgate Energy to be Allocated to Members of PRESTIGE O&G, LLC
1	Caldwell US, Inc.		5,057,885
2	EPMD, LLC		5,057,885
	TOTAL		10,115,770

EX-10.1 4 v367661_ex10-1.htm EXHIBIT 10.1

COALBED METHANE LEASE

THIS AGREEMENT (herein called the "Lease") is made wih an effective date of May 1, 2008 between INTERNATIONAL PAPER COMPANY, a New York corporation, whose address is 7600 W. Tidwell Road, Suite 300, Houston, Texas 77040-5714 acting solely on its own behalf and in the capacities herein expressly stated, "Lessor"), and E&Pco LLC a Texas Limited Liability Company whose address is 2500 Tanglewilde Suite #492 Houston, Texas 77063 , (herein called "Lessee").

1. For value received, Lessor hereby GRANTS, LEASES and LETS exclusively unto Lessee the land as described in Exhibit "A" and shown on Exhibit A-1 attached hereto and made a part hereof and situated in Caldwell Parish, LA (herein called the "Leased Premises"), for the sole purpose of: (a) exploring, drilling, operating for, producing and marketing, coalbed methane gas, gob gas, and their respective constituent products, and any other minerals produced in conjunction with coalbed methane from coal seams, excluding coal, (all such substances are defined for the purpose of this Lease collectively as "CBM") to the extent of Lessor's ownership in these substances, and (b) (but not exclusive of similar use by Lessor, its successor, assigns, grantees or licensees) building roads, laying water and gas pipelines, installing equipment, storing oil, building tanks (but not tank farms), and constructing and laying power stations, power lines, telephone lines, pumping and compressor stations, making land surveys on said land, establishing and utilizing facilities for the surface and subsurface disposal of produced water attributable to the Leased Premises in accordance with the appropriate state and federal regulations, non commercial tower sites and other structures to the extent necessary to investigate , produce, save, dewater, take care of, treat and transport CBM and water attributable to the Leased Premises to the extent of Lessor's rights to grant permission to conduct such activities. It is not the intent of Lessor to lease, and Lessor hereby expressly reserves from the interests leased hereby, any mineral interests (including any undivided or partial interest) on which Lessor owns only the executive privilege, unless this Lease expressly states (i) that such executive privilege is being exercised and (ii) the names of the owners of the mineral interest on whose behalf such executive privilege is being exercised. For purposes of calculating any Shut In Royalty, Delay Rental or Minimum Annual Rental payment herein provided for, Lessor and Lessee stipulate that the Leased Premises shall be deemed to contain 9661 net mineral acres, whether they actually contain more or less; however, this stipulation shall not be effective as to or binding upon Lessor or Lessee for any other purpose. If this Lease now or hereafter covers separate tracts, no pooling or unitization of royalty interest as between such separate tracts is intended or shall be implied or result merely from the inclusion of such separate tracts within this Lease. As used in this paragraph, the words "separate tract" shall mean any tract with royalty or mineral ownership differing, now or hereafter, either as to parties or amounts, from any other part of the Leased Premises. Nothing in this lease shall be construed as granting any rights to recover anything other than CBM and specifically no rights to coal or hydrocarbons from conventional reservoirs are granted hereunder . The use of the term CBM is for convenience and is intended to include names by which CBM is also known, inter alia, such as coal gas, coalseam gas, coalbed gas and firedamp.

COALBED METHANE LEASE - 1

If the Lessor does not own the surface rights to the Leased Premises, the Lessee shall be fully responsible for making all arrrangements with surface owner(s) to allow the Lessee's realization of its rights hereunder. The Lessee is not appointed an agent, representative or partner of the Lessor, and is not authorized or empowered to alter or compromise the Lessor's rights to the Leased Premises.

2. Upon execution of this Lease, Lessee shall pay to Lessor a bonus of $12.00 per net mineral acre in the Leased Premises as set forth on Exhibit "A,". Subject to the further terms hereof, this Lease shall be for a term of three (3) years from this date (the "Primary Term") and as long thereafter as CBM is produced in Paying Quantities from the Leased Premises; or as long as this Lease is continued in effect as otherwise provided herein. Except as otherwise specifically provided herein, "Paying Quantities" shall mean production in quantities sufficient to yield a return on investment in excess of operating costs even though drilling and equipment costs may never be recovered. However, if Lessee can show to the reasonable satisfaction of Lessor that any well(s) that fail to produce in Paying Quantities are necessary for the de-watering process, then such wells shall be deemed to produce in Paying Quantities and shall not be released from the Leased Premises. The status and re-determination, if necessary, of any well that has been "deemed" to produce in Paying Quantities under the foregoing sentence shall be reviewed by Lessee and Lessor from time to time and at a minimum of on an annual basis.

During the Primary Term, Lessee shall be obligated to carry out a minimum drilling program, as set forth below:

l^stLease year: 6 wells or equivalent = 7,920 feet of horizontal laterals

2^ndLease year: 6 wells or equivalent = 7,920 feet of horizontal laterals

3^rd Lease year: 6 wells or equivalent = 7,920 feet of horizontal laterals

As long as the Lease is continued beyond the Primary Term by other provisions contained herein, Lessee will continue to drill a minimum of 12 wells per calendar, or horizontal laterals equivalent = 15,840 feet per year until seventy-five percent (75%) of the net acres in the Leased ?remises have been developed, at which time no further drilling commitment will be required to hold the lease in its entirety. A well shall be defined as a borehole of sufficient depth to test the coal s eams in the Wilcox Formation. Beyond the Primary Term, and until 75% of the net acres in the Leased Premises have been developed , in accordance with the provisions of 3(j) herein below the Lessee shall also make annual minimum royalty payments of $2.00 per net acre on remaining leased acres on the anniversary date of the lease extension in order to maintain its interest in the whole of the Leased Premises. In the event the Lessee drills fewer than the required number of wells in any year after the Primary Term, it shall have no right to drill any further wells in any subsequent year and only those wells and the drilling or spacing unit (Well Tract) acreage assigned to such wells actually in production or capable of being in production (to include any wells being de-watered) shall then comprise the "Leased Premises" for the purpose of this Lease and the Lessee shall have no further interest of any kind in the remaining Lands. Wells drilled in excess of the minimum in any lease year can be credited to the subsequent year.

COALBED METHANE LEASE - 2

3. As used herein the "Royalty Fraction" shall mean a Base Royalty of 12.5_% plus a Supplemental Royalty based on the Gross Sales Price of the CBM, on a well-by-well basis to be determined as follows:

Price at or Then
Greater than		Total Royalty
per MCF of*		Rate of

$	2.50		12.5	%
$	3.00		15	%
$	3.50		16	%
$	4.00		17	%
$	4.50		18	%
$	5.00		19	%
$	5.50		20	%

*Average for month

The royalties to be paid by Lessee to Lessor (at the address shown in Paragraph 20) are:

3. (a)

On coalbed methane, produced from the Leased Premises and sold off such premises, or used off the premises (other than for processing at a plant as described in Paragraph 3(c) · hereof), the royalties shall be the Royalty Fraction multiplied by the gross proceeds received from any sale of such coalbed methane . On CBM produced from the Leased Premises and sold by Lessee, the production royalty to be paid to the Lessor by Lessee shall be .the Royalty Fraction of the gross sales price f.o.b. the "Delivery Point". Delivery Point shall be defined as the point at which the CBM is sold to an unaffiliated third party purchaser or the point at which CBM is delivered to an unaffiliated pipeline for re delivery to a point of sale. Royalties shall not be due on any gas used on the Leased Premises by Lessee.

3. (b)

If the CBM produced from any well situated on the Leased Premises shall contain in suspension condensate, gasoline or other natural gas liquids that economically can be separated from the CBM and liquefied by the installation by Lessee of traps, separators or other mechanical devices ordinarily used in the industry for such purpose, then Lessee shall install such devices on the Leased Premises, and Lessor shall receive the royalty specified in paragraph 3(a) on the condensate, gasoline or other natural gas liquid Hydrocarbons so recovered, together with the royalty specified in Paragraph 3(a) on the residue gas, determined as provided in Paragraph 3(a).

3. (c)

If CBM, gas, or casinghead gas or separated gas resulting from field separation produced from the Leased Premises is processed by or for the account of Lessee, or by or for the account of any Affiliate (as hereinafter defined) for the recovery of liquid hydrocarbons therefrom in a gas processing , absorption. stripping or similar plant, then in lieu of royalties on CBM provided in Paragraph 3(a) or 3(b), (i) the royalties shall be the Royalty Fraction of the Market Value at the plant of all liquid hydrocarbons recovered and saved in such plant and attributable to CBM produced from the Leased Premises, less the Royalty Fraction of the reasonable, direct costs (excluding amortization and depreciation on pipeline and plant investment and direct overhead associated therewith) of processing such CBM in the plant for the recovery of such liquid hydrocarbons, and (ii) the royalties on the residue CBM resulting from such plant operation attn'butable to CBM produced from the Leased Premises shall be in an amount and determined as provided in paragraph 3(a).

COALBED METHANE LEASE - 3

3. (d)

The royalties provided in this paragraph 3 shall be determined and delivered to Lessor free of all cost, including but not limited to any development, production, compression, processing treating, dehydrating, gathering, marketing, transportation, delivery, and other like costs (other than those provided for in Paragraph 3(c) hereof; such royalties shall also bear and be subject to severence taxes applicable to Lessor's share of production that are paid by Lessee. The tenn "Gross Sales Price" as used in this agreement with respect to CBM shal.l mean the final and actual sales price at which CBM ·is sold via an anm length transaction to a Non-Affiliated Bona Fide Third Party Purchaser f.o.b. the Delivery Point, plus BTU bonus or minus BTu penalty without deduction from said gross sales price for any on-site handling, collecting, transportation, dehydrating and compression charges, brokerage fees, sales commissions, credit losses, · sales tax, discounts on sale of promissory notes, bank fees, license tax, privilege tax, occupational tax, advertising, and any other charges whatsoever or taxes paid by Lessee for the privilege of conducting business in, Louisiana or as specified in Paragraph 24 hereof. The tenn "Delivery Point" as used herein shall mean the point at which CBM produced hereunder is delivered, whether from the well head, compressing station, or a point of entry into a third party transmission line or carrier or final end-user purchaser. The tenn "Affiliate" means any individual, corporation, joint venture, partnership or other entity or organization controlling, controlled by or under common control with Lessee (the concept of control meaning the possession, directly or indirectly, of the power to direct or cause the direction of tl:ie management and policies of another, whether through ownership of voting securities (owning 50% or tnore), by contract or otherwise). The term "Bona Fide Third Party Purchaser'' shall mean a purchaser who pays consideration in good faith without intending to take advantage of Lessee or Lessor, and in no instance shall said purchaser include .an individual(s), party, company or corporation which is an Affiliate of Lessee or Affiliate Lessee's successors or assigns.

3. (e)

No shut-in payments are due hereunder during the Primary Term. If at any time, whether before or after the expiration of the Primary Term, Lessee shall have completed on the Leased Premises a CBM well that is capable of producing in Paying Quantities but is shut-in due to the lack of a ready and available market, with the result that CBM is not produced and sold, or used, Lessee shall pay as Shut-In Royalty to Lessor (at the address specified in Paragraph 20) for each shut-in CBM well, on or before the expiration of the later of ninety (90) days after (i) the Completion Date (as hereinafter defined) or (ii) the date such CBM ceases to be sold or used or (iii) after the expiration of the Primary Term, as the case may be, and thereafter at quarterly intervals on the date the first Shut-In Royalty payment is made, an amount equal to two Dollars $2.00 multiplied by the number of acres of the Leased Premises included in the Well Tract (as hereinafter defined) upon which the well is located. During the periods for which such payments are made, it will be considered that such well is producing CBM in Paying Quantities within the meaning of this Lease and the Lease may be extended for the Well Tract from quarter to quarter by timely payment of the quarterly Shut-In Royalty. Lessee may not maintain this Lease as to any Well Tract solely by virtue of the provisions of this paragraph 3. (e) for more than an aggregate of 36 months. Interruption of a continuous shut-in period on a specific well by a return to production of the well for a period of less than forty five (45) days sabll not be considered as interrupting the basis for payment of the shut-in royalty which shall continue to be due and paid quarterly on the basis indicated above.

3. (e)(l)

If at any time Lessee causes CBM to be vented or flared, hereinafter venting, to the atmosphere for a period greater than thirty (30) days, Lessee shall pay to Lessor on a monthly basis two Dollars $2.00 per acre for each acre included in the Well Tract as a Venting Payment, due on or before the last day of the calendar month following the calendar month in which the venting occurred. Venting Payments made under this paragraph 3. (e)(l) shall be considered for each such well as producing in Paying Quantities. Interruption of a continuous venting period on a specific well by a return to production or shut-in of the well for a period of less than forty five (45) days shall not be considered as interrupting the basis for payment of the Venting Payment which shall continue to be due and paid monthly on the basis indicated above. Lessee may not maintain this Lease as to any Well Tract solely by virtue of the provisions of this paragraph 3.(e)(l) for more than an aggregate of 12 months .

COALBED METHANE LEASE - 4

3. (f)

Reporting and payment to Lessor of royalties from the production of CBM shall commence no later than ninety (90) days after the date of first sales from each completed well. Thereafter, unless otherwise specifically provided herein, all reportings and payments of royalties shall be made on or before the last day of the second calendar month following the calendar month in which the production occurred or within fifteen (15) working days after Lessee receives its payment from the CBM purchaser, whichever occurs first. In the event Lessee fails to pay any royalties when due, Lessor reserves the right, but not the obligation. at any time to demand payment of royalties directly from the purchaser of the CBM upon thirty (30) days written notice to Lessee and said purchaser. Reporting shall show for the individual well(s) and the monthly totals: quantities of CBM produced, vented and flared hereunder during the preceeding month; the quantities of CBM sold and used as permitted hereunder, the sales price at the Delivery Point, calculations of the Royalty Fraction to be paid by Lessee and the sales price for all CBM produced from Lessees operations of which the Leased Premises are a part. Royalties or other payments to Lessor provided for in this Lease that are not paid for whatever reason within the time period specified therefor shall accrue mterest at the rate of six percent (6%) per annum in excess of the prime interest rate posted by at least 75% of the nation's largest banks as published in the Wall Street Journal, per annum, from due date until paid, provided that such interest rate shall be reduced automatically to the legal maximum rate in the event same ever exceeds such maximum rate. Acceptance by Lessor, its successors, agents, or assigns, of royalties that are past due shall not act as a waiver or estoppel of its right to receive or recover interest due thereon under the provisions hereof. No tender or payment to Lessor of a sum less than the total amount due to Lessor shall be deemed a full settlement, whether by accord or satisfaction or otherwise, notwithstanding a check in tender of payment may contain language of settlement or accord printed or otherwise inserted thereon unless made and received in accordance with a separate written agreement executed by Lessor and Lessee. Lessee shall furnish Lessor on a monthly basis copies of all reports submitted to the Louisiana State Oil and Gas Board or other regulatory authority showing quantities of Hydrocarbons and water produced from each well located on the Leased Premises and all production sales records and all other data relative to the calculation and payments of royalties. Lessee shall keep all proper records to enable a correct determination of all CBM produced and marketed (or delivered to Lessors' credit in pipelines or otherwise), to which records Lessor or their duly authorized agents shall have access to at all reasonable times for a period of three (3) years after the making of any such payments for the putpose of audit or verification of the statements furnished by Lessee to lessor.

3. (g)

Notwithstanding the provisions of Paragraph 3.(f), Lessor and Lessee agree that the payment and reporting to Lessor of all royalties then. due from the production of CBM on or before the last day of the second ·calendar month following the calendar month in which the production occurred shall be deemed a condition of this Lease. Should this condition be breached, subject to the provisions of Section 3(f) hereof,J,essor shall have the right at the election of Lessor, to give written notice to Lessee and Lessee shall have thirty (30) days from receipt of said written notice in which to cure the breach by the payment and reporting of all royalties then owing, plus the interest provided for in paragraph 3(f). If Lessee fails to cirre the breach within said thirty (30) day period then Lessor may, at its option, terminate this Lease. In the·absence of an adverse claim against Lessor's title, Lessee shall have no right to withhold or suspend any funds claimed by Lessor without the prior written consent of Lessor. Lessee shall pay all reasonable attorney fees incurred by Lessor in connection with any lawsuit in which Lessor is successful in recovering royalties or .interest or in confirming this Lease's termination due to Lessee's failure to pay and report royalties within the periods set forth in this Lease.

3. (h)

Each demand for payment of royalty by Lessor, made as a predicate to Lessor's termination of this Lease, shall contain a demand for a specific amount of royalty and describe the time period for which the royalty payment is due. In the event Lessee disputes liability for paying all or any portion of the demanded royalty, Lessee shall, within thirty (30) days of the receipt of such demand, pay any amounts of royalty which are due to Lessor and undisputed by Lessee, and Lessee shall, in Writing, descnbe to the Lessor the specific reasons why Lessee claims that it does not owe the disputed amounts to Lessor. Within ten (10) days of the receipt of Lessee's response to Lessor's demand, if Lessee disputes the amount of any royalties demanded, representatives of Lessor and Lessee shall meet to attempt, in good faith, to resolve the dispute with regard to the amount of royalties owed. In the event that such dispute cannot be resolved within thirty (30) days of Lessor's receipt of Lessee's response to Lessor's demand for payment of royalties, the parties shall submit suGh dispute to . arbitration before the American Assod.ation of Arbitr.cition pursuant to its Rules for the Resolution of Commercial Disputes. If the amount in dispute is under $1,000;000, only one arbitrator shall be appointed. If the. amount m-dispute iS in excess of $, 000,000, the arbitration panel shall be composed of three arbitrators, each of whom shall have at least ten. (10) years of experience in the oil and gas industry and none of whom shall have, within five (5) years of the date of their appointment, been employed by; sociated with, or provided professional services to either Lessor or Lessee. In the ev.ent a three (3) member panel of arbitrators is required, each party shall be entitled to appoint one (1) arbitrator, and the two arbitrators shall select a third arbitrator. If the two arbitrators are unable to select a third arbitrator, the third arbitrator shall be appointed by the United States District Judge sitting for the Souhem District of Texas, Houston Division. In such arbitration proceedings, the evidence adduced shall be governed by the Federal Rules of Evidence. The arbitration proceedings shall be held in Houston, Texas, or at such other location as may be .agreed to by the parties or ordered by the arbitrators. In the event the arbitration panel issues an award stating an amount of unpaid royalties owed to Lessor, Lessee shall make full payment of the award within thirty (30) days of its rendition. During the pendency of the dispute over unpaid royalties, including arbitration proceedings, Lessor shall not tenninate the Lease; provided, however, should the arbitration award determine that Lessee did not exercise good faith in disputing the amount of royalties owed, the arbitration panel may, in addition, provide for terrniilation of the Lease. Any arbitration award entered by the arbitration panel determining that Lessor is entitled to tennination of the Lease shall be subject to appeals available from arbitration awards. Should the arbitration panel so determine, it may suspend the award of termination of the Lease pending the appeal from the arbitrator's award. The Lessee shall pay all arbitration costs if the panel awards a settlement in favor of Lessor.

COALBED METHANE LEASE - 5

3. (i)

Notwithstanding the provisions of this Paragraph 3 to the contrary, Lessor shall have the right and option, but not the obligation, to take in kind all or part of Lessor's Royalty Fraction of all CBM produced under the terms of this Lease and to separately market such CBM for Lessor's own account. Lessor's option may be exercised at any time and from time to time by Lessor giving Lessee not less sixty (60) days advance written notice. Lessee agrees that all CBM contracts which obligates Lessee to sell gas for greater than a thirty (30) day term shall include a provision whereby the Lessor has the right to take in kind and separately market Lessor's royalty share of CBM, and Lessee shall expressly provide in the contracts that the CBM transmission carrier shall be obligated by contract to carry the Lessor's royalty share of CBM on the same terms, conditions and at a rate not greater than the rate applied to lessee's CBM. In the event Lessor elects to take in kind Lessor's royalty CBM, Lessee agrees to deliver such CBM into the sales pipeline free of all cost and expense to Lessor except Lessor's share of severence taxes. Should Lessor elect not to take in kind its Royalty Fraction of any Cl3M produced hereunder after having done so, Lessor shall notify Lessee, upon sixty (60) days written notice, of Lessor's desire to no longer take said royalty in kind and it shall be Lessee's obligation to market said production for Lessor and to pay Lessor's royalty according to the terms of this Lease.

3. (j)

If, during any calendar year after the Primary Term while this Lease is in force, CBM shall be produced from any well on the Leased Premises, but there has not been paid hereunder to Lessor the sum of at least $2.00 per net acre during that year for each net acre subject to this Lease at the end of such year, by way of shut-in CBM well royalties and/or royalties paid on actual production, Lessee shall, within ninety (90) days after the end of such lease year, pay or tender to Lessor (at the address specified in Paragraph 20), as a minimum annual royalty, the difference between the total of such production royalty and shut in gas royalty payments made under this Lease during such lease year and said sum of $2.00 per net mineral acre multiplied by the number of net acres to which this Lease is in force at the end of such calendar year. The payment of minimum annual royalty provided for in this Paragraph 3U) shall not be in lieu of actual production of CBM in paying quantities and Lessee shall not be entitled to continue this Lease in force by payment of such minimum royalty if, in fact, the actual production of CBM is not in paying quantities as determined in accordance with the provisions of Paragraph 2 above. It is further provided that nothing contained in this Paragraph 3U) shall be construed as preventing or delaying the termination of this Lease under the provisions of Paragraph 4 hereof, nor as impairing Lessee's continuing obligation to reasonably develop the Leased Premises after the discovery of CBM thereon in paying quantities, in accordance with this Lease, nor as in any manner impairing Lessee's continuing obligations to protect the Leased Premises from drainage by wells on adjoining or adjacent lands, as provided in Paragraph 6 hereof.

3. (k)

Measurement of CBM. (a) The unit of vol\IDle for measurement of the CBM produced hereunder shall be one (1) cubic foot of gas at a base temperature of 60 degrees Fahrenheit and at an absolute pressure of fourteen and seventy-three hundredths (14.73) pounds per square inch, absolute ("PSIA"). All fundamental constants, observations, records and procedures involved in determining and/or verifying the quaritity and other characteristics of gas delivered hereunder, unless otherwise specified herein shall be in accordance with the standards prescribed in Report No. 3 of the American Gas Association ("AGA'') as now and from time to time may be amended or supplemented.. All measurements of CBM shall be determined by calculations in the terms of such unit All quantities given herein, unless expressly otherwise stated, are in tenm of such unit (b) Lessee or the purchaser of production, as required by Lessee and under Lessee's direction and supervision shall maintain and operate at its sole expense measuring stations located at each wellhead.. Said measuring stations shall be equipped with turbine or rotary meters or other types of meters with totalizer as agreed to by Lessor and Lessee so as to accomplish the accurate measurement of volumes of CBM produced hereunder. (c) Lessor may at its option and expense install check meters for checking Lessee's metering equipment and the same shall be so installed as to not interfere with the operation of Lessee's facilities . (d) The specific gravity of the CBM flowing through the meter or meters shall be detemrined monthly by the use of an AGA accepted gravitometer or by computing from fractional analysis of samples of the CBM taken at as many points as necessary to permit the calculation of an average specific gravity representativ e of all the CBM produced hereunder. Specific gravity so determined will be used in calculating gas production for the month in wruch the tests are made. (e) The Gross Heating Value of the CBM shall be determined by taking continuous samples at as many points as necessary to permit the calculation of an average Gross Heating Value representative of all CBM produced and sold hereunder. .The sample may be run on a calorimeter or Gross heating Value may be computed from fractional analysis of such sample. The result shall be applied to CBM produced during the month in which samples are taken. (f) Ifupon any test, the metering equipment in the aggregate is found to be inaccurate by two (2) percent or more, registration thereof or any payment based upon such registration shall be corrected at the rate of such inaccuracy which is definitely known or agreed upon, or if not known or agreed upon, then for a period extending back one-half of the time elapsed since the previous calibration. Following any test, any metering equipment found to be inaccurate to any degree shall be adjusted immediate ly to measure accurately.

COALBED METHANE LEASE - 6

4. If Lessee has not met its minimum annual drilling program as set out in Paragraph 2 hereof, as of each respective anniversary date, the Lease shall terminate as to the undeveloped acreage unless on or before such respective anniversary date Lessee shall pay or tender the sum of $2.00 per net undeveloped mineral acre, (being $2.00 times the number of undeveloped acres in the Leased Premises) (herein called "Delay Rental") to Lessor at the following address: International Paper Minerals Division, 7600 W. Tidwell Road, Suite 300, Houston, Texas 77040- 5714, Attention: Manager Mineral Resources.Such payment shall cover the privilege of deferring the respective annual minimum drilling program for a period of twelve 02) months. The payment or tender of Delay Rental may be made by check delivered on or before the due date for such payment to Lessor at the address designated above or to such other address hereafter specified in written notice from Lessor to Lessee, said written notice to be delivered to Lessee at least forty-five (45) days prior to any particular anniversary date. Lessee may at any time execute, file in the proper public records and deliver to Lessor a rel;;se or releases covering any portion or portions of the Leased Premises and thereby surrender this Lease as to such portion ot portions and be relieved of all obligations not theretofore accrued as to the acreage surrendered, and thereafter the Delay Rental hereunder and the Minimum Annual Rental payable in accordance with paragraph 3G) shall be reduced in the proportion that the acreage covered hereby is reduced by such release or releases. Any bonus or other payµient or consideration paid by Lessee to Lessor for this Lease shall not be credited, allocated or prorated to or against the Delay Rentals provided for in this paragraph. Ifduring the Primary Term Drilling Operations (as hereinafter defined) are commenced on the Leased Premises, this Lease will remain in effect as to the entirety of the Leased Premises without the further payment of annual Delay Rentals only for so long as Continuous Operations (as hereinafter defined) are prosecuted or the minimum annual drilling commitment has been met. Should Lessee thereafter during the Primary Term hereof cease to conduct such Continuous Operations, or if all of the Leased Premises are not maintained by Continuous Operations or the minimum annual drilling commitment has not been met, this Lease shall terminate as to all portions of the Leased Premises not then included in Well Tracts (as hereinafter defined) unless on or before the date on which the next subsequent well is required to be commenced, or on or before the anniversary date of a respective annual minimum drilling program, whichever date is later, Lessee pays or tenders to Lessor, in the manner Specified above, Delay Rentals equal to $2.00 times the number of net undeveloped acres in the Leased Premises located outside of existing Well Tracts, and thereafter resumes payment of annual Delay Rentals thereon as hereinabove provided . Delay Rentals can not extend the lease longer than three(3) years under any circumstances.

COALBED METHANE LEASE - 7

5.(a) As used in this Lease, the terms "Operations," "Drilling Operations,"Continuous Operations" and "Other Operations" shall have the meanings set forth in Paragraph 5(d) hereof

5.(b) In the event Lessee at any time drills a dry Hole on the Leased Premises and no CBM is then being produced in paying quantities hereunder, 0r in the event all production of CBM in paying quantities from the Leased Premises should at any time cease for any cause and this Lease is not otherwise being maintained, this Lease shall continue in effect for a period of ninety (90) days from abandonment of such dry hole or cessatioh of production and may be ;

continued thereafter under the following conditions:

5(b)(l) If Lessee commences Operations on the Leased Premises within such 90 day period, this Lease shall continue in effect as long as IDrilling Operations or Other Operations are prosecuted with due diligence and so long ther1after as CBM is produced hereunder; provided however, this Lease may not be maintained so. ely by Other Operations for any period in excess of ninety (90) consecutive days unless the minimum annual drilling commitment is continually met or delay rentals have been paid.

5.(c) If no CBM is being produced from the Lease Premises at the expiration of the Primary Term, but Lessee is then engaged in Drilling Opera,ons, or if within the ninety (90)day period specified in Para,graph 5.(b) above Lessee commenies Drilling Operations, this Lease shall continue in effect in the manner and for the time speci:fi.4 in Paragraph 5.(e) hereof.

5.(d) For purposes of this Lease:

5.(d)(l) The term "Drilling Operations" shAfl mean that a derrick, a rig and machinery capable of drilling a depth sufficient to test the prospective coalseam horizon at the permitted depth has been erected on the Leased Premises and tJiat such rig is rotating under power.

5.(d)(2) The term "Other Operations" shalll include all completion or abandonment operations, reworking, reconditioning, deepening, p1ugging back, cleaning out, repairing, testing or dewatering of a well being conducted with eqiliptnent customarily used in the industry for such operations, in a prudent manner with reasona le diligence in a bona fide good faith effort to obtain, maintain, enhance and/or restore the prMuction of CBM in Paying Quantities. Coal desorption testing beyond 90 days from coal core retrieved shall not meet the definition of "Other Operations" under this Lease.

5.(d)(3) The term "Operations " shall mean ither Drilling Operations or Other Operations, or both.

5.(d)(4) The completion date of a produchlg well is herein defined as: (i) the date thirty (30) days following the running of final producti9n casing and/or liner in the hole, or, (ii) thirty (30) days following the date total depth is r ached, or (iii) the date of completion as reported to the statewide conservation agency or co:rrlmission having jurisdiction, whichever is the earlier date. The completion date of a well whic results in a dry hole and is abandoned shall be the date upon which all work in the hole has be completed and the plug is set, or the drilling rig ceases to operate on such well, whichev¢r is the earlier date.The commencement date of Operations not specifically set forth in this pfu-agraph shall be the date on which the equipment required to conduct such Operations in the manner specified herein has been installed on the well and the actual operation thereof has commenced; and the completion or cessation of any such Operations shall be deemed to have occurred on the earlier of the date such Operations are discontinued or the date such equipment is removed from the well.

COALBED METHANE LEASE - 8

The cessation of production from a well shall be deemed to have occurred when actual production has ceased, without any reasonable expectation of resumption of production in Paying Quantities from that well; and except for a gas well on which Shut-In Royalty payments have been paid under paragraph 3(e) above, a well shall be conclusively presumed to have ceased production without reasonable expectation of resumption thereof if no CBM is produced in Paying Quantities for a period of ninety (90) consecutive days, and no Operations are conducted thereon during such ninety (90) day period.

5.(d)(5) Operations shall be Continuous Operations if not more than ninety (90) days elapse.betWeen the completion or abandonment of Drilling Operations on one well and the Commencement of Drilling Operations on another well.

5.(e) This Lease shall continue in force as to all of the Leased Premises so long as Lessee is engaged in Continuous Operations (as hereinabove defined) on the Leased Premises and production in paying quantities continues, subject to the limitations set forth in this Paragraph 5.(e). Upon Lessee's failure to maintain Continuous Drilling Operations this Lease shall tenninate except as follows:

5.(e)(l) If Lessee has completed a CBM well on the Leased Premises, then this Lease shall continue as to and only as to the intervaJ from the surface to 100 feet below the base of the deepest producing Coal Seam in such well, insofar as such interval pertains to a tract of a maximum of one hundred sixty (160) surface acres, plus or minus a tolerance of 10%, around each such well. The respective surface acres and strata thereunde!perpetuated as prescribed above shall be referred to herein as a "Well Tract". In the event any federal or state law, or any order, rule or regulation of the statewide conservation agency or commission having jurisdiction prescribes a spacing pattern for the development of the field, or allocates a producing allowable in whole or in part based on surface acreage per well or based upon the acreage to be drained by a well drilled horizontally , or otherwise in an articulated manner, then any Well Tract retained hereunder may include as much additional acreage as may be so prescribed or as may be used in such allocation or allowable. If such "order" results in a spacing pattern or allocation of allowable based on acreage which amount is less than that originally established, then each such Well Tract shall be revised to include such lesser .amount of acreage. Such reduction shall be immediately effective and Lessee shall then comply with the continuous drilling provisions of Paragraph 5. Each Well Tract shall, as nearly as practicable , be in the fonn of a square or a rectangle with the well by virtue of which same is held located in the approximate center thereof. However, as an overriding consideration, Lessee shall form each Well Tract so as to best utilize all available acreage covered by this Lease and so as not to leave acreage outside of a Well Tract which cannot be utilized or included in subsequently created Well Tracts.

COALBED METHANE LEASE - 9

5.(e)(2) If the statewide conservation agency or commission does not prescribe a spacing unit and pattern, then within ninety (90) days after the completion date of any producing well, Lessee shall designate to Lessor in writing a Well Tract for each such well, with the producing stratum or strata defined with particularity by reference to Lessee's well logs. Lessee shall file a memorandum in the proper county records describing the Well Tract or Well Tracts. After the expiration of the Primary Term, and the expiration of compliance with the continuous development obligations herein described, each Well Tract shall constitute a separate Lease with the terms of this Lease, and neither production from nor Operations on any other Well Tract or any other portion of the Leased Premises shall maintain this Lease in force as to any other Well Tract. The determination of a well's classification as CBM by a governmental authority shall be controlling as between Lessor and Lessee for all purposes of this Lease; provided however, if it is subsequently determined that such classification is not correct, Lessor's and Lessee's rights under this Lease shall in no way be limited or impaired thereby.

5.(f) Lessee may at any time execute, file in the proper public records and deliver to Lessor a release or releases covering any portion or portions of the Leased Premises and thereby surrender this Lease as to such portion or portions and be relieved of all obligations not theretofore accrued as to the acreage surrendered.

6. In the event a well or wells producing CBM should be brought in draining the Leased Premises, Lessee agrees to drill such offset wells as a reasonable and prudent operator would drill under the same or similar circumstances. Without limiting the foregoing, it shall be presumed that any producing CBM well situated within 500 feet of the Leased Premises, is draining the Leased Premises. Operations for any such offset well to be drilled to protect the Leased Premises from drainage shall be commenced within one hundred twenty (120) days after commencement of production from the draining well and continued with due diligence and in a prudent manner with no cessation of Operations of more than thirty (30) days. It is further provided that in lieu of drilling such offset well, Lessee may, at its option, within the one hundred twenty (120) day period, release the Lease as to that portion of the Leased Premises lying adjacent to such draining well. The portion of the Leased Premises so released shall be as nearly as practical in the form of a square or rectangle (either in stand-up or laydown form) and shall be 160 acres or such larger area as may be permitted or prescribed by the appropriate governmental authority for the draining well.

7. Lessee recognizes that Lessor does not own the surface estate associated with the Lease Premises and that Lessor only is leasing whatever right it may have relative to the coalbed methane on the lease premises. At least three days . prior to commencement· of seismic or operations other than drilling hereunder, Lessee will contact said Regional Manager and.Lessor notifying them of the date and locations where said operations will be conducted, and an estimate of the time necessary for its completion with a copy to Lessor. Lessor does not grant permission for said seismic surveys without the permission of the surface owner. Upon receipt of such notice, Lessor will furnish Lessee with its then current fee schedule for seismic damages, if applicable. In the event Lessee performs, or causes to be performed, any seismic operations on the Leased Premises, Lessee agrees to pay Lessor, or the applicable surface owner, the amounts set forth in such fee schedule. Lessee agrees to make such payment promptly upon the completion of said seismic operations by check payable to INTERNATIONAL PAPER COMPANY or the applicable surface owner. Such payment shall be for minimum damages to the surface of the Leased Premises.Any excessive damages as determined by the Regional Manager, as a result of said seismic operations, shall be borne by Lessee. It is understood that notwithstanding the criteria set out in this clause that the provisions of applicable legislation, rules and policies will override the criteria and that such must be complied with by the Lessee. It is also understood by the Lessee that such legislation, rules and policies may be in the process of being changed to reflect CBM. It is the responsibility of the Lessee to obtain all necessary permits and authorizations necessary for the conduct of its operations and the Lessor agrees to cooperate with respect to obtaining such permits or authorizations when necessary or appropriate.

COALBED METHANE LEASE - 10

8. It is expressly agreed and understood that the Lessee is not granted any right to voluntarily pool, combine or unitize the Leased Premises in which Lessor owns one hundred percent (100%) of the CBM rights with any land not covered by this Lease without the prior written consent of Lessor. Lessee shall notify Lessor in writing not less than ten (10) days prior to Lessee's commencement of any action to institute or support any statutory, administrative or regulatory action to combine, pool or unitize the Leased Premises with any lands not covered by this Lease. Said notice shall include copies of any support materials available to Lessee which would aid Lessor in assessing the consequences of the proposed action. Additionally, Lessee shall notify Lessor in writing upon receiving notice that a third party intends to institute such action to combine, pool or unitize the Leased Premises with lands not covered by this Lease, such notice to be given within five (5) days of Lessee's receipt thereof, or in any event within a time sufficient to permit Lessor to participate in any proposed hearing or proceeding. In the event any part of the land included in this Lease is unitized by order of any governmental authority having jurisdiction for production of oil and/or gas/and or CBM then, notwithstanding anything to the contrary contained in this Lease or in the unit order, and whether or not the unit well is located on the Leased Premises, the royalty herein reserved in favor of Lessor on production from such unit shall be calculated and paid on the proportion of the land included in this Lease bears to the land included in the whole government approved well-site spacing unit.

9. This Lease does not include and there is hereby excepted and reserved to Lessor all minerals except "CBM" as defined in Paragraph 1, including but not limited to sulphur (except when produced as a constituent element), coal, lignite, iron ore, limestone, uranium and other fissionable materials, geothermal energy (including hydrostatic pressur e and . thermal energy), base and precious metals and other mineral and non-mineral substances, presently owned by Lessor in, under or upon the Leased Premises, together with the rights of ingress and egress and use of the Leased Premises by Lessor and its mineral lessees, for purposes of exploration for and production of the non-CBM minerals reserved herein to Lessor. Lessor and Lessee each shall conduct their respective operations on the Leased Premises so as not to unreasonably interfere with the operations or activities of the other. Gob gas is considered CBM and for the purpose of this Lease is defined as that gas which is liberated and accumulates within the fractured collapse zone resulting from the underground mining of coal seams.

COALBED METHANE LEASE - 11

10. The rights of either party hereunder may be assigned in whole or in part and the provisions hereof shall extend to the respective heirs, executors, administrators, successors and assigns of the parties hereto; provided, however that any such assignment by Lessee shall require the prior written consent of Lessor, and such consent shall not be unreasonably withheld. If Lessor denies Lessee's request to assign, Lessor may, at its sole discretion, agree to grant such consent after an amendment of the terms contained herein, including, but not limited to: a) increased insurance requirements, b) bonding or letters of credit covering financial obligations, plugging, abandonment, restoration, or other mutually agreed considerations. No change or division in Lessor's ownership of the land, rentals or royalties however accomplished shall operate to enlarge the obligations or diminish the rights of Lessee, nor shall any such change or division be effective for any purpose until the person acquiring any interest has furnished Lessee with the instrument or instruments, or certified copies thereof, constituting the change of title from Lessor. Notwithstanding the foregoing, if Lessee elects to assign any part or all of Lessee's rights and interests hereunder, Lessee and Lessee's assignees shall remain liable and responsible to Les.sor (unless released in writing by Lessor) for all surface and subsurface damages which may be caused to the Leased Premises, both before and after the effective date of any .such assignment, and shall remain bound by all of the terms, conditions and covenants, both express and implied, of this Lease, including the payment of royalty. Lessee shall comply and cause any successor assignee to comply with all valid laws, rules, and regulations affecting the Leased Premises and all operations thereon.

Notwithstanding any consent to assignment, in whole or in part, Lessor shall retain the right and in its sole discretion havethe right to approve any operator, including any party which may take an assignment of Lessee's interest in the Leased Premises. In the event Lessee elects not to act the capacity of operator in conducting the drilling or production operations for any well drilled under the terms of this Lease_, Lessee shall furnish Lessor a written notice which informs Lessor of such election and which simultaneously designates a proposed substitute operator for approval by Lessor. Lessor reserves the absolute right to approve or disapprove any such proposed substitute operator and no operations may be conducted on the Leased Premises by any such proposed substitute operator until Lessor has furnished Lessee a written notice of such approval. Any written request by Lessee for Lessor's consent to assign its operating rights hereunder must be accompanied by evidence acceptable to Lessor that the proposed operator/assignee has the financial and technical capabilities to undertake the obligations and liabilities imposed by the terms and conditions ofthis Lease unless such requirement is waived in writing by Lessor.

11. In no event shall Lessee enter into a contract for the sale of Lessor's Royalty Fraction of CBM which does not provide for at least semi-annual redetermination of the prices paid for CBM sold under any such contract. Lessee shall not enter into any contract with any Affiliate relative to the sale, gathering, treating, compressing, marketing, operating, transporting or processing of any CBM produced from the Leased Premises without the prior written consent . of Lessor. IfLessee enters into any such Affiliate contract without Lessor's prior written consent, Lessor shall have the right to unilaterally declare that all royalties have not been paid and that a default has occurred under the provisions of Paragraph 3.(g) of this Lease .

COALBED METHANE LEASE - 12

12. This Lease is granted without any covenant of title or warranty of title of any kind whatsoever, expressed or implied, and Lessee shall have no recourse against the Lessor in the event of any failure of title, nor shall any of the consideration paid hereafter, or any delay rentals or shut-in payments made hereunder be refunded to Lessee, except as otherwise expressly stated herein. Lessee shall have the right to purchase, pay or redeem any mortgage, tax or other lien on the Leased Premises and be subrogated to the rights of the holder thereof. Lessee at its option may discharge any tax lien upon Lessor's interest in the Leased Premises (unless such tax lien is being contested in good faith by Lessor by appropriate proceedings instituted for such purpose) and, in the event Lessee does so, Lessee shall have the right to apply royalties hereunder to reimburse such payment after notice thereof to Lessor. IfLessee obtains a title opinion or title insurance policy on any portion of the Leased Premises, Lessor will be provided a copy of such title material at no cost to Lessor. Lessee may undertake title curative work for the purpose of which is to affirm Lessor's title or possession of the Leased Premises. The results of any such curative work shall be furnished to Lessor.

13. Except as expressly limited in this paragraph but otherwise notwithstanding any other provision of this Lease, if this Lease covers a lesser interest inthe CBM in all or any part of said land other than the 100% CBM estate, or no interest therein, then the Delay Rentals and minimum annual rentals and CBM royalties, shall be paid only in the proportion which the interest therein, if any, covered by this Lease, bears to the whole 100% CBM estate therein. The Bonus Payments shall be due and payable notwithstanding that the ownership of the CBM estate shall be determined or believed to be less than 100%. The Bonding requirements shall remain the same notwithstanding the determination of any reduction in the Lessor's CBM interests. Should any lands covered by this Lease be subject to a nonparticipating royalty interest, the royalty to be paid to Lessor herein shall be proportionately burdened or reduced by said nonparticipating royalty interest. Lessor's royalty shall proportionately bear such nonparticipating royalty interests and Lessee shall, prior to the date herein above set out for the first payment of royalty from each well herein, notify Lessor in writing of the existence of such nonparticipating royalty, such notice shall specifically describe the creating of such interest and shall include copies of the instruments creating a nonparticipating royalty to the extent, and only to the extent that such interests would be borne by Lessor if the owners of those interests adopted and ratified the terms of this Lease, whether or not such adoption or ratification has in fact occurred. Proceeds due any other third party for production from a well on the Leased Premises shall be borne by Lessee.

14. Lessee is hereby granted the right, subject to the provisions of Paragraph 16 of this Lease, to conduct or cause to be conducted, those operations which it deems reasonably necessary for its development of the Leased Premises. Such operations may be conducted, with the permission of the surface owner, by Lessee, its agents, representatives, and contractors solely for Lessee's benefit, and the right to conduct such operations may not be assigned by Lessee to any other party unless the grant includes all or a portion of the leasehold operating interest created by this Lease. Notwithstanding anything in this Lease to the contrary, Lessor reserves the right to conduct, or grant the right to conduct to third parties, exploratory operations on the Leased Premises in respect of the non-CBM and other Hydrocarbon and non-Hydrocarbon estate.

COALBED METHANE LEASE - 13

All such rights are subject to legislation, rules and policies as may exist from time to time as established by the Commission .

15. The execution of division orders shall never be required as a prerequisite for payment of royalty or any other monies accruing under this Lease. Any amendment, alteration, extension or ratification of this Lease or of any term or provisions hereof shall be made by a recordable instrument titled "CBM Lease Amendment'' executed by Lessor and Lessee, and any purported amendment, alteration, extension or ratification not so drafted and executed shall be of no force or effect. (Insert statement of equivalents **)

16. The provisions ofthis paragraph shall be operative as to (i) the Leased Premises and (ii) any lands pooled therewith (the "Area").

16. (a) Lessee shall notify Lessor:

16. (a)(l) inwriting , no later than ten (10) days prior to the commencement of any seismic or drilling operations, including the location of any proposed seismic operations and the location and objective depth of any proposed well.

16. (a)(2) either orally or inwriting, at least forty-eight (48) hours prior to commencement of any operations to test, log or plug any well.

16. (a)(3) either orally or in writing , at least twenty-four (24) hours prior to conducting any completion or coring operations on any well.

16. (a)(4) inwriting , as to the date any well is (i) commenced, (ii) completed, (iii) plugged or (iv) shut-in, within twenty-four (24) hours of same.

16. (b) Lessee shall furnish Lessor the following information for each well (including exploration core holes) drilled within twenty-four (24) hours after such information is made, produced or obtained by Lessee:

1. Daily drilling and mud log reports.

2. Samples of all cores and samples taken from the mud or coring.

3. Complete copies of all logs and electrical survey runs showing formations encountered and the identification of such formations as determined by Lessee, its geologists or paleontologists. Also, Lessee shall furnish Lessor with log data in LAS Fonnat or other format requested by Lessor on 3W' floppy disk or CD-Rom.

4. Results of all tests, including drill stem tests, formation tests, core analyses, water quality, desorption results, and vitrinite reflectance.

5. All dipmeter and velocity surveys, including Lessee's interpretations thereof.

6. Adsorption isotherm data and vitrinit e reflectance data.

COALBED METHANE LEASE - 14

7. Copies of all permits or forms filed with the Oil and Gas Commission or any governmental agency.

8. Monthly production reports and information regarding the sale of CBM and its respective constituent products produced hereunder.

9. Surveys of the Leased Premises, including location plats, made by or for Lessee annually update and submit

10. Such other information and data as the Lessor may reasonably request, all of which information shall be held by Lessor as confidential information, which shall not, without the prior written consent of Lessee, be disclosed in any way to any other person, firm or business entity.

16. (c) Lessee shall submit to Lessor on an annual basis a map showing the well locations and designation of all Well Tracts.

16. (d) Ifpermitted by third party contacts, Lessee shall furnish Lessor copies of all proprietary seismic and geophysical data owned by Lessee, including source tapes, field data and associated documentation and the results of any reprocessing of such data. In addition, if so permitted, Lessee shall furnish copies of all seismic and geophysical data acquired by or used by Lessee after the date of this Lease including copies of source tapes, field data and associated documentation and the results of any reprocessing of such data relating to lines crossing the Area, and any other seismic data generated as a result of such seismic operations from which Lessee is required to furnish data to Lessor

16.(e) Information furnished to Lessor hereunder may be used for its own purposes or that of any affiliated, subsidiary; provided, however, Lessor and/or its affiliated subsidiary companies agree that such information shall be maintained confidential by Lessor and/or its affiliated and subsidiary companies for a period of one (1) year from the date such information becomes available to Lessor.

17. During the term of this lease, Lessor and/or its'authorized representatives, at Lessor's sole risk and expense, shall have full rights of ingress and egress to the Area and any lands pooled therewith for the purpose of inspecting drilling or producing operations, machinery, equipment and all other operations or purposes which Lessor may consider necessary or advisable. Additionally, upon not less than five (5) days' advance notice to Lessee, Lessor and/or its authorized representatives, shall have the right, during regular business hours at Lessee's office, to inspect, examine, make copies of and extracts from Lessee's books, records, accoWlts, contracts, commitments and agreements insofar as they relate to the Leased Premises, operations thereon or production therefrom (including, without limitation, the information referred to in Paragraph 16 above).

COALBED METHANE LEASE - 15

18 (a). Prior to Lessee abandoning any wells on the Leased Premises Lessor shall have the right, within thirty (30) days (twenty-four (24) hours if a rig is on location) after receipt of notice of Lessee's intention to so abandon, to take over the well or wells. Lessor shall give Lessee written notice of its intention to take over any such well or wells on or before the expiration of such thirty ( 30) day or twenty-four (24) hour period, whichever is applicable If the well is taken over by Lessor and results in a completion attempt wherein a well capable of production is encountered, then all of Lessee's right and interest in such well shall be owned by Lessor as provided hereinafter. It is expressly understood that Lessee's interest in and rights to such well and its associated Well Tract may be subject to agreements under which other parties may have a contractual right to take over said well and to acquire all, or a portion, of Lessee's rights, exclusive of those to be earned by Lessor hereunder. In the event one or more parties having such right, including Lessor, desire to take over the well, this Lease shall be released to Lessor (as to the well and its associated Well Tract as hereinafter provided); provided that Lessor agrees to pay Lessee the reasonable salvage value of any salvageable material in the hole which Lessee has contributed, less the cost of salvaging same. Should Lessee fail to comply with the terms and conditions of this Paragraph 18 prior to plugging any well on the Leased Premises, Lessee shall pay to Lessor $ 100,000 as liquidated damages for such noncompliance.

IfLessor takes over the well and the completion attempt results in a dry hole, Lessor agrees to plug and abandon the well or wells at its sole cost, risk and expense and Lessee's rights hereunder shall remain in full force and effect.

Likewise, if Lessor takes over the well, but no operations are conducted in said well by Lessor and Lessor notifies Lessee within 30 days after Lessor took over said well that Lessor is releasing said well, then, and in that event, Lessee agrees to plug and abandon the well or wells at its sole cost, risk and expense.

Upon receipt of such notice from Lessor after the takeover of a well that the Lessor has completed a well capable of production., Lessee shall promptly deliver to Lessor a release of all of its interest in the Well Tract for such well, made pursuant to the provisions of Paragraph 5 relating to termination of the Lease as to Well Tracts and Lessor shall pay to Lessee the salvage value of the salvageable material for the well determined in accordance with the provisions of customary accounting procedures . The material shall then be conveyed to Lessor by an itemized bill of sale free and clear of all encumbrances.

Lessor's rights and Lessee's obligations under this Paragraph 18 shall not be effective so long as Lessee maintains the Lease as to the Well Tract for such well by Other Operations (excluding abandonment) or by Drilling Operations as provided in Paragraph 5.

18 (b) Plugging and other covenants.

Lessee shall comply with all rules and regulations of the State of Louisiana concerning the casing of wells or the plugging of dry and abandoned CBM wells, and with any other laws pertaining to CBM wells.

COALBED METHANE LEASE - 16

Lessee shall plug all holes and abandon CBM wells in accordance with the rules and regulations of the State of Louisiana in accordance with the following:

CBM wells shall be mapped by a registered land surveyor to locate the collar and elevation of the holes on the surface.

Appropriate well logs shall be run in the well to detennine the exact depth and thickness of all coal seams. The logs to be run shall include at a minimum gamma ray, bulk density and caliper. Lessor shall have the right to run additional logs of its own at a time convenient to Lessee. Lessor shall bear the cost of any expenses incurred for said additional logging.

Surface casing shall be left in the hole as specified in the drilling permit.

Lessee shall notify Lessor in writing at least thirty (30) days prior to the beginning of any well plugging operation as per Paragraph 18(a).

18 (c) Restoration

Lessee agrees, upon the completion or abandonment of each well drilled by it on the Leased Premises, to promptly restore the surface of the Leased Premises to as near the same condition as it was prior to the drilling of said well as is practicable. Such surface restoration shall include, without limitation, reforestation, the cleaning and levelling of all locations, the filling and levelling of all mud pits or other excavations, including roads, the removal of all drilling mud and drilling fluids from such pits and other excavations prior to the filling and levelling thereof . Ifthe relevant well is abandoned as a dry hole or after the cessation of production, Lessee shall remove all fences, equipment, machinery, and tanks, and all other structures, concrete or other foundations or property of any kind or character as soon as possible after the cessation of such operations but no later than three (3) months after the abandonment of each drill site.

19. (a). Lessee agrees to indemnify and hold Lessor harmless from any claim or cause of action by any person whomsoever arising out of or in connection with its operations on the Leased Premises, including, but not limited to any claims by the owner of the surface or other mineral interest holders. Inthe event Lessor is made a party defendant in any claim for loss, injury, or damages to persons or property arising out of or in connection with Lessee's operations on the Leased Premises or lands pooled therewith, Lessee agrees to defend Lessor at its sole cost and expense and satisfy any judgment which may be rendered against Lessor. IfLessee fails or refuses to retain counsel and actively defend any such suit, Lessor may retain counsel of its choice to defend the action. Lessee in such event shall be liable for reasonable attorneys' fees, court costs, including expert witne'Sses, and the amount of any money judgme nt which may be awarded against Lessor.

COALBED METHANE LEASE - 17

19. (b).Lessee on behalf of itself and its directors, officers, employees, agents, consultants, contractors, licensees and invitees and their respective successors and assigns (collectively, the "Releasors") shall indemnify and hold harmless Lessor and its directors, officers, employees, agents consultants, contractors, licensees and invitees and their respective heirs, executors, administrators, successors and assigns (collectively, the "Releasees"), and each of them, from and against any and all liens, claims, demands, suits, actions, causes of action, costs, expenses, losses, damages and liabilities (including without limitation special, exemplary or consequential damages and economic loss and including losses from property damage, personal injury or death), orders including penalties and fines imposed pursuant to any federal or state legislation, and judgments, suffered or incurred by the Releasees or any of them or brought, made or

imposed against the Leased Premises or lands pooled therewith or against the Releasees or any of them, in respect of, as a result of or arising from:

(i) any personal injury (including death resulting at any time therefrom) or property damage or loss suffered or incurred on the Leased Premises or lands pooled therewith in connection with any operation or activity of the Releasors or any of them or any exercise or purported exercise of the CBM Rights or any rights ancillary thereto; or

(ii) any breach or default in the due observance or performance of the obligations of Lessee under this Lease; or

(iii) any negligence or wilful misconduct on the part of the Releasors or any of them on or with respect to the Leased Premises or lands pooled therewithor with respect to the CBM Rights or any exploitation thereof; or

(iv) any damage to or contamination of the Leased Premises or lands pooled therewith or any improvements thereto or any other environmental damage caused by the Releasors or any of them or arising from or as a result of any exercise or purported exercise of the CBM Rights or any rights ancillary thereto; or

(v) the CBM Rights, or any activity or operations of the Releasors or any of them on or with respect to any part of the Leased Premises or lands pooled therewith, or any act or omission of the Releasors or any of them with respect to or in connection with the CBM Rights or the exercise or exploitation thereof under this Lease or otheiwise.

19 (£) Lessor and any third party having coal mining rights granted by Lessor shall have no responsibility for the shortening of the productive life or the reduction in the amount ofrecoverable reserves from any Well Tract or portion of the Leased Premises as a result of coal mining activities on the Leased Premises ("Mine Through").

COALBED METHANE LEASE - 18

20. Except with respect to notices and reports required to be given pursuant to the provisions of Paragraph 16 hereof, any notice or other communication permitted or required under the terms hereof shall be in writing and, unless othelWise specified, shall be deemed properly given on the ate personally delivered or on the date postmarked if mailed, registered or certified, by postage prepaid and United States mail, addressed to Lessor or Lessee at the addresses set forth below, or to such other address as may hereafter be designated by either party to the other by notice.

Notice given in any other manner shall be effective only if and when received.

Except as expressly provided herein to the contrary, all notices and reports , required under this Lease shall be delivered to Lessor at the following address:

International Paper Company

Mineral Resources Division

7600 W.Tidwell Rd., Suite 300

Houston, Texas 77040-5714

Attention: Manager Mineral Resources

Physical Address:

International Paper Company

Mineral Resources Division

7600 W.Tidwell Rd.,Suite 300

Houston, Texas 77040-5714

All payments, royalty payments and royalty reports shall be made and delivered to Lessor on the due dates set forth herein at the following address:

International Paper

Mineral Resources Division

7600 W.Tidwell Rd.,Suite 300

Houston, TX 77040-5714

Telephone numbers listed for convenience:

Phone Number (713) 651-2768

Fax Number (713) 951-4554

Email address: ________________

All notices required under this Lease from Lessor to Lessee shall be delivered to Lessee at the following address:

E&Pco

2500 Tanglewilde

Suite 492

Houston, TX 77063

Telephone numbers listed for convenience:

Phone Number 713-978-6503

Fax Number 713-978-6772

COALBED METHANE LEASE - 19

21. Upon expiration or termination of this Lease for any reason as to all or any portion of the Leased Premises, Lessee at its sole cost and expense shall promptly prepare, execute and file in the appropriate Parish land records office an appropriate release instrument covering all or such portion of such land, and shall forward a copy of same as recorded to Lessor. Failure to provide Lessor with a recorded copy of said instrument within ninety (90) days after the expiration of the Primary Term (or any other time at which there has been a termination of the rights under this Lease, whether partial or complete) will result in a penalty to Lessee of $100.00 per: day until said instrument is provided to Lessor. The daily penalty shall not begin to accrue until 30 days after Lessor has notified Lessee in writing to file such release. The penalty will be due and payable on demand of Lessor.

22. Lessee, if not in default hereunder, and provided Lessor does not elect to take over any well(s) shall have the right at any time during or within one hundred eighty (180) days after the expiration of this Lease to remove all property and fixtures placed by Lessee on the Leased Premises, including the right to draw and remove all casing; provided that, Lessor shall have the right to acquire any fresh water wells drilled by Lessee on the Leased Premises by paying Lessee the salvage value of the equipment in and on such well less the cost of salvaging the same. All property and fixtures not removed within such one hundred eighty (180) day period will become the property of the Lessor or the surface owner, except that if Lessor at any time during or within ten (10) days after the expiration of this Lease requires in a written notice to Lessee that any of such property be removed, Lessee shall remove the same within such one hundred eighty (180) day period, or, in the event Lessee fails so to do, Lessor may remove same at the sole cost, risk and expense of Lessee.

23. During the term of this Lease, Lessee shall, at its expense, maintain in force and effect minimum insurance in a form subject to approval of Lessor and with an insurance company approved by Lessor as follows:

A. Comprehensive General Liability Insurance, with limits of liability of not less than the following:

	Bodilyinjury/PropertyDamage
	Combined any one occurrence	$1,000,000
	Aggregate	$2,000,000

Such insurance shall include the following:

Contractual Liability, insuring the indemnity agreements contained in this contract.

Coverage for property damage due to blasting and explosion, structural property damage, underground property damage, and surface damage from blowout and cratering.

Lessee shall purchase Extended Reporting Provision if policy is written on a claims-made basis and is non-renewed or cancelled.

COALBED METHANE LEASE - 20

B. Comprehensive Automobile Liability Insurance, with limits of liability of not less than the following:

Bodilylnjury/PropertyDamage

Combined any one accident or occurrence $2,000,000

Such coverage shall include owned, hired and nonowned v ehicles.

C. Excess Liability Insurance with limits of liability of not less than $5,000,000.

D. Environmental Impairment Liability Insurance with limits of liability of not less than $5,000,000.

Each insurance policy maintained by Lessee, must be endorsed as follows:

Lessor, its owners, subsidiaries and affiliated companies, as well as their employees, officers, and agents shall be named as "Additional Insured ." (Except for Workmen's Compensation policy).

All coverages shall contain waivers of subrogation (whether by loan receipts, equitable assignment, or otherwise) against Lessor, its owners, subsidiaries and affiliated companies, as well as their employees, officers and agents.

The coverage afforded herein shall be primary in relation to any policies carried by Lessor, its subsidiaries, owners and affiliated companies, as well as their employees, officers and agents.

In addition to the above insurance requirements the Lessee shall obtain coverage under the Workers Compensation Act and regulations and the Lessee shall be considered to be the "Prime Contractor" under the Workers Compensation Act and regulations . The Lessee shall also require that all subcontractors be in compliance with the provisions of the Workers Compensation Act and regulations.

Lessee shall furnish Lessor with certificates of insurance evidencing compliance with this obligation prior to commencement of operations hereunder and shall give Lessor ten (10) days notice of any proposed change of insurance carriers or coverage.

24. During the term of this Lease, Lessee shall be responsible for and pay when due, or reimburse Lessor for if paid by Lessor, any and all taxes payable in respect to the CBM, or any exploitation, or production, or operation, or activity, or property or improvements by the Lessee on the Leased Premises or with respect to the CBM, including all real and personal property taxes, assessments and charges and Lessee shall provide proof of payment to Lessor promptly. Lessor shall provide copies of all such notices to Lessee upon receipt.

In the event Lessee fails to pay any royalty or any other sum due to Lessor under this Agreement in the manner so prescribed , Lessor shall have, without notice to Lessee or demand to Lessee, a perfected security interest and a lien on all machinery, equipment, structures, and other property of Lessee of every kind located on the Leased Premises at the time of default and thereafter. If such a default in payment continues for more than thirty (30) days, the above granted lien may be enforced as provided by the laws of the State of Louisiana, including but not limited to the Uniform Commercial Code.

COALBED METHANE LEASE - 21

25. The Lessee shall give Lessor prompt written notice of any claims of or by third parties or any other event or circwnstance that could adversely affect the ability or legal right of the Lessee to produce, save, take clear title to and sell CBM from the LeIased Premises pursuant to the CBM rights granted herein(the "Adverse Claims"). The Lessee shall use all reasonable commercial efforts to resist and defend against any Adverse Claims, anh shall not, without Lessor's prior written corisent, which will not unreasonably be withheld, settle any Adverse Claims in any manner that could adversely affect the ability or legal ri*t of the Lessee to produce, save, take clear title to and sell CBM from any part of the Leased Premises pursuant to any of the rights granted herein. Lessor shall have the right at Lessor's !expense to participate in resisting and defending against any Adverse Claims and at its option to!assume conduct thereof, in its own name or in the name of the Lessee or both.

The Lessee shall pay and continue to pay the CBM royalty as provided herein notwithstanding any Adverse Claims, provided that to the extent the payments hereunder=would be reduced if an Adverse Claim were successful, the Lessee may pay the proportionate part of each subsequent

payment that would be applicable to such reduction, into trust an escroYi account or registry of a court of competent jurisdiction in the State of Louisiana pending final resolution or settlement of the Adverse Claim, on terms that provide for payment thereof according to such final resolution or settlement including payment to Lessor in the event that the Adverse Claim is not upheld.

26. Notwithstanding any operational standards set out in thi Lease, it is understood and agreed that all rights granted hereunder are subject to the applicable laws of the State of Louisiana without limiting the generality of the foregoing the applicable provisions of the Petroleum and-Natural Gas Act, the Oil and Gas. Comm-i-s--s-i--o. n..·.A_,_c_t, the.Coal Act, the Forest Practi Mines Act. Failure to comply with any provisions of applicable laws will allow the Lessor at its option to terminate this Lease by giving notice pursuant to Section 20.

27. All references to currency are in United States funds.

28. (a) This Agreement is and will be deemed to have been made in Louisiana, and for all purposes will be governed exclusively by and construed·and enforced in accordance with the laws prevailing in the State of Louisiana and the rights and remedies of the parties will be detennined in accordance with those laws. ·

28. (b) Each of the parties irrevocably attoms to the jurisdiction of the courts of Louisiana and all courts having appellate jurisdiction thereover and agrees that any proceeding commenced or maintained in respect of or arising as a consequence of this Lease will be commenced or maintained only in such of those Courts as is appropriate.

29. (a) All questions or matters in dispute with respect to accounting, engineering or · technical matters, other than disputes over royalty payments which shall be governed by paragraph 3(h) hereof, will be submitted to arbitration pursuant to the terms of this Section 29. All arbitrators appointed shall be knowledgeable with respect to the subject matter or question.

COALBED METHANE LEASE - 22

29. (b) It will be a condition precedent to the right of any party to submit any matter to arbitration pursuant to the provisions of this Section 29, that any party intending to refer any matter to arbitration will have given not less than thirty (30) days' prior written notice of its intention so to do to the other party together with particulars of the matter in dispute.

29. (c) On the expiration of such thirty (30) days, the party who gave such notice may proceed to refer the dispute to arbitration as provided in Paragraph 29.(d). The parties may appoint a single arbitrator by mutual agreement.

29. (d) In the event the parties do not appoint a single arbitrator, the party desiring arbitration will appoint one arbitrator, and will notify the other party of such appointment, and the other party will, within 15 days after receiving such notice, appoint an arbitrator, and the two arbitrators so named, before proceeding to act, will, within 15 days of the appointment of the last appointed arbitrator, unanimously agree on the appointment of a third arbitrator to act with them and be chairman of the arbitration herein provided for.

29. (e) Ifthe other party will fail to appoint an arbitrator within 15 days after receiving notice of the appointment of the first arbitrator, and if the two arbitrators appointed by the parties fail to agree on the appointment of the chairman, the chairman will be appointed under the provision of the American Arbitration Association.

29. (£) Except as specifically otherwise provided in Paragraph 30.(d) the arbitration herein provided for will be conducted in accordance with such Rules of the American Arbitration Association for the Resolution of Commercial Disputes ("Rules").

29. (g) The chairman, or in the case where only one arbitrator is appointed, the single arbitrator, will fix a time and place in Houston, Texas, for the purpose of hearing the evidence and representations of the parties, and he will preside over the arbitration and determine all questions of procedure not provided for under such Rules or Paragraph 30.(d).

29. (h) After hearing any evidence and representations that the parties may submit, the single arbitrator, or the arbitrators, as the case may be, will make an award and reduce the same to writing, specifying the time frame for the award and deliver one copy thereof to each of the parties.

29. (i) The expense of the arbitration will be paid as specified in the award.

29.(j) The parties agree that the award of a majority of the arbitrators, or in the case of a single arbitrator, of such arbitrator, will be final and binding upon each of them, subject only to the limited appeals from arbitration awards.

30. (a) The parties agree to keep confidential certain information. "Confidential Information" is defined as

COALBED METHANE LEASE - 23

(i) all information, data, kriowledge, and know-how (in whatever form and however communicated) relating, directly or indirectly, to Lessor (or to itsaffiliates or to its or their business, operations, properties, products, markets, or financial positions) that is delivered or disclosed by Lessor or any of its officers, directors, partners, members, employees, agents, affiliates, or shareholders to Lessee in writing, electronically, verbally, or through visual means, or which Lessee learns or obtains orally, through observation or through: analyses, interpretations, compilations, studies, or evaluations of such information, data, knowledge, or know-how, but

(ii) does not include information, data, knowledge, and know-how, as shown by written records, that

(A) is in Lessee's possession before disclosure to Lessee,

(B) is in the public domain before disclosure to Lessee, or

(iii) includes all analyses, interpretations, compilations, studies, and evaluations of such information, data, knowledge, and know-how generated or prepared by or on behalf of Lessor or Lessee.

30. (b) The term "document," as used inthis Lease, includes any writing, instrument, agreement, letter, memorandum, chart, graph, blueprint, photograph, financial statement, or data, telex, facsimile, cable, tape, disk, or other electronic, digital, magnetic, laser, or other recording or image in whatever form or medium.

30. (c) Recipient will use the Confidential Information solely for the Purposes of carrying out its obligations under the Lease and for no other purpose. ·

30. (d) Lessee will keep the Confidential Information confidential and not disclose the Confidential Information to any person or entity other than

(i) such of Lessee's officers, directors, partners, members, employees, attorneys, accountants, or financial advisors who have a bona fide need to have access to sucb Confidential Information in order for Lessee to carry out the Purposes, and

(ii) such other persons as Lessor hereafter agrees inwriting may receive such Confidential Information (which agreement may be withheld for any reason or for no reason).

30. (e) Lessee will be responsible and liable for any use or disclosure of the Confidential Information by such parties in violation: of this Agreement.

30. (f) Nothing contained herein will be deemed to prevent disclosure of any of the Confidential Information if, such disclosure is legally required to be made in a judicial, administrative, or governmental proceeding pursuant to a valid subpoena or other applicable order, but, Lessee will

COALBED METHANE LEASE - 24

(i) give Lessor at least 10 days written notice (unless less time is permitted by the applicable proceeding) before disclosing any Confidential Information in any such proceeding and, in making such disclosure,

(ii) disclose only that portion thereof required to be disclosed, and

(iii) will take all reasonable efforts to preserve the confidentiality thereof, including obtaining protective orders and supporting Lessor in intervention.

31. This Lease may be executed in multiple counterparts, each of which shall be deemed an original for all purposes and all of which taken together shall constitute a single document, but shall not be effective unless executed by all the Parties hereto.

32. The obligations of the parties under this Lease are subject to extension due to force majeure as defined in this paragraph. If either party hereto is rendered unable, wholly or in part, by force rnajeure to carry out its obligations under this Lease, other than the obligation to make money payments, that party shall give to the other party hereto prompt written notice of the force majeure with reasonably full particulars concerning it; thereupon, the obligations of the party giving the notice, so far as they are affected by the force majeure, shall be suspended during, but no longer than, the continuance of the force majeure. Force Majeure does not begin and shall not be effective for any purpose under this Lease until the other party shall have received written notice of the force majeure condition from notifying party. The affected party shall use all reasonable diligence to remove the force majeure situation as quickly as practicable. The requirement that any force majeure shall be remedied with all reasonable dispatch shall not require the settlement of strikes, lockouts, or other labor difficulty by the party involved, contrary to its wishes; how all such difficulties shall be handled shall be entirely within the discretion of the party concerned once the cause of force majeure is eliminated, the claiming party shall promptly recommence operations. The term "force rnajeure" as here employed, shall mean an act of God, strike, lockout, or other industrial disturbance, act of the public enemy, war, blockade, public riot, lightning, fire, storm, flood, explosion, governmental action, governmental delay, restraint or inaction, unavailability of equipment, and any other cause; whether of the kind specifically enumerated above or otherwise, which is not reasonably with in the control of the party claiming suspension. Lessor on prior written notice may terminate this Lease if a cause of force majeure claimed by Lessee lasts longer than 365 days.

33. Severability -Ifany provision of this Lease or the application thereof to Lessor or Lessee shall, for any reason and to any extent, be held to be invalid or unenforceable, the remainder of this Leased agreement shall not be affected thereby, but rather shall be enforced to the greatest extent permitted by law.

COALBED METHANE LEASE - 25

34. Binding Effect -This Lease agreement shall inure to the benefit of and be binding upon the successors and assigns of Lessor and Lessee.

INWITNESS WHEREOF, the parties have executed this Lease effective as of the date first above written.

LESSOR:

	LESSOR:

	INTERNATIONAL PAPER COMPANY

	By:	/s/ R.T. Kaczorowski
		R.T. Kaczorowski
		Agent and Attorney-in-Fact

	LESSEE:
	E&Pco

	By:	/s/ Charles E. Edwards


	Title:	CHIEF EXECUTIVE OFFICER

Instrument Prepared by:	INTERNATIONAL PAPER COMPANY
	P.O. Box 4258
	Houston, Texas 77210

COALBED METHANE LEASE - 26

EXHIBIT "A"

Attached to and made a part of that certain Coalbed Methane Lease between International Paper Company, as Lessor and E&Pco, as Lessee, dated May 1, 2008.

The Leased Premises shall consist of the CBM Interests owned by International Paper Company

in the following described lands located in Caldwell Parish, LA

Caldwell Parish, LA -Exhibit A Property Description: 9661± acres

Tl3N -R5E

Section 1	Entire Section

Section 2	NE 4
	E2 of NW4
	NW4 of NW4
	SW4 -A11lying N & E of Morengo Lake and Bayou
	SE4

Section 12	Entire Section

Section 13	Entire Section

Section 24	Entire Section

Section 25	Entire Section lying N of Boeuf River ·

T13N -R6E

Section 5	Lot 3 (SW4 of SW4 lying S & W of Boeuf River)

Section 6	Lot 3, 4 & 5 (All lying S & W of Boeuf River)

Section 7	Entire Section

Section 8	Lots 3, 4 & 6 (All lying S & W of Boeuf River)

Section 17	Lots 2, 3, 4, 5, 6 & 7 (All lying W of Boeuf River)

Section 18	Entire Section

Section 19	Lots 1, 2, 3, 4, 5, 6 & 7 (All lying W of Boeuf River)

Section 20	Lots 2, 3, 4, 5 & 8 (All lying W of Boeuf River)

Section 30	Entire Section N & W of Boeuf River

Section 21	Lot 4 (All of NW4 lying W of Boeuf River)

Section 21	Lot 5 (All of SW4 lying W of Boeuf River)

T14N -R5E

Section 25	Lots 5, 6, 7 & 8 (All lying S of Boeuf River)
	S2 of SW4
	S2 of SE4

COALBED METHANE LEASE - 27

Section 26	Lots 2, 8 & 9 (All lying S of Boeuf River)
	SW4 of SW4
	SE4 of SE4

Section 27	Lots 2, 8 & 9 (All lying S of Boeuf River) E2 of SE4
	NW4 of SE4

Section 35	Entire Section

Section 36	Entire Section

Tl4N -R6E

Section 30	Lot 5 (All lying S & W of Boeuf River)

Section 31	Lots 2 & 3 (All lying S & W of Boeuf River)

COALBED METHANE LEASE - 28

EXHIBIT "A-1"

Attached to and made a part of that certain Coalbed Methane Lease between International Paper Company, as Lessor and E&Pco, as Lessee, dated May 1, 2008 .

Map ofLeased Premises

COALBED METHANE LEASE - 29

Dear Osman,

Attached please find a copy of the lease agreement which is certified and registered in the Caldwell Parish Clerk of Records. (file # 222364)

This goes along with item #7 of the outstanding list.

Regards,

Charles E. "Chuck" Edwards

E&Pco, LLC

2500 Tanglewilde, Suite 492

Houston, Texas 77063

Direct: 713-978-6503

Fax: 713-978-6772

E-mail: chuckedwards@e-pco.com

EX-10.2 5 v367661_ex10-2.htm EXHIBIT 10.2

AMENDMENT TO : Coalbed Methane lease between E &Pco, LLC and International Paper in Caldwell Parish, LA. dated 1st day of May, 2008 .

This Amendment , with an effective date of April 30, 2011 by and between BRP LLC, successor in interest to INTERNATIONAL PAPER COMPANY, hereinafter sometimes referred to as "Lessor" and E &Pco LLC, a Texas limited liability company hereinafter sometimes referred to as "Lessee."

WITNESSETH:

WHEREAS, it is the mutual desire of Lessor and Lessee to amend provisions of said Agreement as hereinafter provided;

NOW THEREFORE , for and in consideration of the negotiated sum of $19,322 and other good and valuable consideration , the receipt and sufficiency of which are hereby acknowledged , it is agreed that:

The primary term of the lease is extended by 12 months, until April 30, 2012.

Except as amended hereby, said Lease Agreement shall remain unchanged.

WITNESSES:	LESSOR:
	BRP LLC

	/s/ R. T. Kaczorowski
	R. T. Kaczorowski, Vice President-Operations
	Date: 6/10/2011

WITNESSES:	LESSEE:
	E &Pco, LLC

	/s/ Osman Kaldirim,Jr
	Osman Kaldirim, Jr., Vice President
	Date: 6/14/2011
STATE OF TEXAS

COUNTY OF HARRIS

Before me, the undersigned authority, on this day personally appeared Osman Kaldirim, Jr, Vice President of E &Pco LLC,, LLC a limited liability company, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed, in the capacity stated, and as the act and deed of said limited liability company .

Given under my hand and seal of office this 14^thday June 2011.

	/s/ Donna C Brook
	Notary Public in/and for	Harris Country
	The State of Texas
	My commission expires:	12/13/2012

STATE OF TEXAS	§
	§
COUNTY OF HARRIS	§

Before me, the undersigned authority, on this day personally appeared RAY T. KACZOROWSKI, Vice President-Operations for BRP LLC, a Delaware limited Liability Company, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed , in the capacity stated, and as the act and deed of said corporation.

Given under my hand and seal of office this 10^th day of June 2011.

	/s/ Patricia A. Smith
	Notary Public in/and for	HARRIS Country
	The State of Texas __
	My commission expires:	9/12/2011

AMENDMENT TO : Coalbed Methane lease between E &Pco, LLC and International Paper in Caldwell Parish, LA. dated 1^stday of May, 2008.

This Amendment , with an effective date of April 30, 2012 by and between BRP LLC, successor in interest to INTERNATIONAL PAPER COMPANY, hereinafter sometimes referred to as "Lessor" and E &Pco LLC, a Texas limited liability company hereinafter sometimes referred to as "Lessee."

WITNESSETH:

WHEREAS, it is the mutual desire of Lessor and Lessee to amend provisions of said Agreement as hereinafter provided;

NOW THEREFORE, for and in consideration of the negotiated sum of $19,322 and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged , it is agreed that:

The primary term of the lease is extended by 12 months, until April 30, 2013.

Except as amended hereby, said Lease Agreement shall remain unchanged.

WITNESSES:		LESSOR:
		BRP LLC


/s/ Randy R. Cornele		/s/ R. T. Kaczorowski
Randy R. Cornele		R. T. Kaczorowski, Vice President-Operations
		Date: 5-1-2012

WITNESSES:		LESSEE:
		E &Pco, LLC


		/s/ Osman Kaldirim,Jr
		Osman Kaldirim,Jr., Vice President
		Date: 4/30/2012

STATE OF TEXASC

OUNTY OF HARRIS

and as the act and deed of said limited liability company.

Given under my hand and seal of office this 30^thday April 2012.

	/s/ Tashfeen Brohi
	Notary Public in/and for	Houston
	The State of	IX
	My commision expires	June 1,2012

STATE OF TEXAS	$
	$
COUNTY OF HARRIS	$

Before me, the undersigned authority, on this day personally appeared RAY T. KACZOROWSKI, Vice President-Operations for BRP LLC, a Delaware limited Liability Company, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed, in the capacity stated, and as the act and deed of said corporation.

Given under my hand and seal of office this 2^ndof MAY 2012

	/s/ Donna C Brook
	Notary Public in/and for	Harris County
	The State of	Texas
	My commision expires	12/13/2012

AMENDMENT TO : Coalbed Methane lease between E &Pco, LLC and International Paper in Caldwell Parish, LA. dated 1st day of May, 2008.

This Amendment, with an effective date of April 30, 2013 by and between BRP LLC, successor in interest to INTERNATIONAL PAPER COMPANY, hereinafter sometimes referred to as “Lessor” and E &Pco LLC, a Texas limited liability company hereinafter sometimes referred to as “Lessee.”

WITNESSETH:

WHEREAS, it is the mutual desire of Lessor and Lessee to amend provisions of said Agreement as hereinafter provided;

NOW THEREFORE, for and in consideration of the negotiated sum of $19,322 and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, it is agreed that:

The primary term of the lease is extended by 12 months, until April 30, 2014.

Except as amended hereby, said Lease Agreement shall remain unchanged.

		LESSOR:
		BRP LLC

		/s/ R.T. Kaczorowski
		R. T. Kaczorowski, Vice President-Operations
		Date: 4/9/2013

WITNESSES:		LESSEE:
		E.&Pco, LLC

		/s/ Osman Kaldirim
		Osman Kaldirim, Jr., Vice President
		Date: 4/5/2013

STATE OF TEXAS

COUNTY OF HARRIS

Given under my hand and seal of office this 5^th day April 2013.


	Notary Public in/and for
	The State of Texas
	My commission expires: August 16,2014

STATE OF TEXAS	§
	§
COUNTY OF HARRIS	§

Before me, the undersigned authority, on this day personally appeared RAY T. KACZOROWSKI, Vice President-Operations for BRP LLC, a Delaware limited Liability Company, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed, in the capacity stated, and as the act and deed of said corporation.

Given under my hand and seal of office this 9^th day of April 2013.


	Notary Public in/and for
	The State of Texas
	My commission expires: 12/13/2016

EX-10.3 6 v367661_ex10-3.htm EXHIBIT 10.3

2001 Bryan Street

Suite 3700

Dallas, Texas 75201

www .regenyenergy.com

January 25, 2010

Osman Kaldirim, Jr.

E&Pco, LLC

2500 Tanglewilde

Suite 260

Houston, Texas 77063

	Re:	Regency Intrastate Gas LP
		Facility Construction and Reimbursement Agreement
		Tap, Valve and Meter Installation
		IPCO #1 Interconnect, Section 21-T14N-R5E
		Caldwell Parish, Louisiana

Dear Mr.Kaldirim:

This Facility Agreement shall indicate the mutual agreement of Regency Intrastate Gas LP ('RIGS"), and E&Pco, LLC ("E&Pco") to install a tap, valve and metering facilities for the receipt of gas by RIGS from E&Pco under the following terms and conditions:

Facilities: Prior to the construction of any facilities contemplated hereunder, RIGS must obtain all permits and approvals as required by any agencies having jurisdiction over RIGS. Upon receipt of all necessary permits or regulatory approvals, RIGS will install, own, and maintain on or a new meter station consisting of a 6" tap and a 3" meter tube and associated piping, valves, flow control, over pressure protection valve, flanges and fittings ("Meter Station") to be located near Section 21-Tl4N-R5E on Regency's existing 30" pipeline in Caldwell Parish, Louisiana (the "Facilities"). Exhibit A attached hereto sets forth in detail the responsibilities of Regency Intrastate and E&Pco.

Reimbursement: E&Pco shall reimburse RIGS for all costs actually incurred by RIGS associated with the construction of the Facilities. All costs and charges shall be paid in advance of any work performed by RIGS. RIGS has estimated the total costs hereunder to be $221,000 ("Estimate"). E&Pco and RIGS recognize that the Estimate may not be equivalent to the total actual RIGS costs and, that E&Pco shall be solely responsible for and shall reimburse RIGS for the total actual RIGS costs, if any, that exceed the Estimate. RIGS shall promptly notify E&Pco in writing if RIGS reasonably anticipates that the actual costs will exceed the Estimate. Within sixty (60) days after completion of the installation of the Facilities, RIGS shall either (a) invoice E&Pco for the total actual costs incurred by RIGS in excess of the Estimate if actual costs exceed the Estimate or (b) refund to E&Pco any amounts paid that exceeded the actual costs if the actual costs were less than the Estimate; provided, however, that RIGS shall not be obligated to invoice or refund amounts less than $100. E&Pco shall pay the full Estimate prior to installation of the Facilities.

Operations and Maintenance: RIGS shall have the on-going right to perform, or to have performed, any future construction, inspections, repairs, additions, modifications, upgrades, replacements, removal, disconnect, abandonment, and, if necessary, retirement of the Facilities deemed necessary by RIGS, and any associated costs shall be reimbursed by E&Pco. E&Pco shall provide RIGS or its representatives full access, rights, permission, and authority for ingress to and egress from the.Facilities as long as such Facilities are in service.

If E&Pco materially fails to comply with any provision of this Agreement (excluding by reason of force majeure), then RIGS shall have the right, upon reasonable notification to E&Pco and subject to any necessary regulatory authorizations , to suspend the flow of gas through the Facilities. E&Pco shall reimburse RIGS for any costs incurred as a result of such suspension, and for reestablishing the flow of gas through the Facilities. RIGS shall not be required to resume gas flow through the Facilities until E&Pco has corrected, in RIGS's reasonable judgment , the area(s) of noncompliance with this Agreement.

Other Agreement(s): Nothing in this Agreement shall be construed to grant E&Pco any transmission rights on RIGS pipeline system. RIGS' receipt of Gas at the new receipt point will be subject to the terms and conditions of the applicable Transportation Agreement(s) and the Operating Statement of Regency Intrastate Gas LP ("RIGS Operating Statement").

Indemnity

Indemnity by E&Pco: E&Pco shall defend, indemnify and hold harmless RIGS, its parent, subsidiaries and affiliates, and their respective agents, officers, directors, representatives and employees (collectively "RIGS Indemnified Parties") from and against any and all claims, demands, causes of action, settlements, liabilities, losses, costs, damages, fines, judgments or expenses (including without limitation, fees and disbursements of counsel incurred by the RIGS Indemnified Parties in any action or proceeding between the indemnifying party and the RIGS Indemnified Parties or between the RIGS Indemnified Parties and any third party or otherwise) (collectively "Claims") arising from or related in any way to (i) an actual or asserted failure of E&Pco or its designee to comply with this Agreement and/or any law, ordinance, code, rule or regulation of any governmental body, or (ii) injury to or death of persons arising in whole or in part and directly or indirectly out of the acts or omissions of E&Pco or its designees, agents, or contractors , but excepting, in the case of either clause (i) or clause (ii) above, injury or death of persons or damage to or loss of property to the extent caused by the gross negligence or willful misconduct of the RIGS Indemnified Parties.

Indemnity by RIGS: RIGS shall defend, indemnify and hold harmless E&Pco, its parent , subsidiaries and affiliates, and their respective agents, officers, directors, representatives and employees (collectively "E&Pco Indemnified Parties") from and against any and all claims, demands, causes of action, settlements, liabilities, losses,costs, damages, fines, judgments or expenses (including without limitation, fees and disbursements of counsel incurred by the E&Pco Indemnified Parties in any action or proceeding between the indemnifying party and the E&Pco Indemnified Parties or between the E&Pco Indemnified Parties and any third party or otherwise) (collectively "Claims") arising from or related in any way to (i) an actual or asserted failure of RIGS or its designee to comply with this Agreement and/or any law, ordinance, code, rule or regulation of any governmental body, or (ii) injury to or death of persons arising in whole or in part and directly or indirectly out of the acts or omissions of RIGS or its designees, agents, or contractors, but excepting, in the case of either clause (i) or clause (ii) above, injury or death of persons or damage to or loss of property to the extent caused by the gross negligence or willful misconduct of the E&Pco Indemnified Parties.

Page 2

Insurance: E&Pco will carry or cause to be carried and maintained in force throughout the entire term of this Agreement insurance as described below with reliable insurance companies. The limits set forth are minimum limits and will not be construed to limit E&Pco's liability.

Workers' Compensation insurance with statutory limits in compliance with all applicable state and federal laws having jurisdiction over each employee and Employer's Liability insurance with limits of $1,000,000 each accident, $1,000,000 disease each employee and $1,000,000 disease policy limit.

Commercial General Liability insurance on an occurrence form with a combined single limit of $1,000,000 each occurrence and annual aggregates of $1,000,000, for bodily injury and property damage, including coverage for contractual liability, independent contractors, broad form property damage, products/completed operations and explosion, collapse and underground.

Automobile Liability insurance with a combined single limit of $1,000,000 each occurrence for bodily injury and property damage to include coverage for all owned, non-owned and hired vehicles.

Excess or Umbrella Liability insurance with a combined single limit of $1,000,000 each occurrence, and annual aggregates of $1,000,000 for bodily injury and property damage covering excess of Employer's Liability, General Liability, and Automobile Liability insurance described above.

In each policy of the above-described insurance, E&Pco, with respect to its obligations, agrees to waive and will require its insurers to waive any rights of subrogation or recovery they may have against RIGS.

E&Pco agrees to submit a certificate(s) of insurance evidencing compliance with the insurance requirements set forth in this article.

Page 3

Force Majem:e: In the event of either Party hereto being rendered unable, wholly or in part, by force majeure to carry out its obligations under this Agreement , the obligations (other than the obligation to pay money) of such Party, so far as they are affected by such force majeure, shall be suspended during the continuance of any inability so caused, but for no longer period, and such cause shall be remedied with all reasonable dispatch. It is agreed that such Party shall give notice and full particulars of such force majeure in writing by U.S. mail, e-mail or by facsimile to the other Party as soon as reasonably possible after the occurrence of the cause relied on.

The term "force majeure" as employed herein shall mean acts of God, strikes, lockouts or other industrial disturbances, acts of .the public enemy, wars, blockades, insurrections, riots, epidemics, landslides, lightning, earthquakes, fires, storms, floods, washouts, arrests and restraints of governments and people, civil disturbances, explosions, breakage or accident to natural gas processing and/or treating facilities, wells, machinery or lines of pipe, the necessity for making repairs or alterations to wells, equipment or lines of pipe, freezing of wells or lines of pipe, or any other causes, whether of the kind herein enumerated or otherwise, not within the control of the Party claiming suspension, and which by the exercise of reasonable diligence, such Party is unable to prevent or overcome. It is understood and agreed that the settlement of strikes or lockouts shall be entirely within the discretion of the Party experiencing the strike or lockout.

Pressure and Quality: Deliveries of gas to RIGS by E&Pco shall be at a pressure sufficient to allow gas to enter RIGS's pipeline against the pressure existing therein from time to time, provided that the pressure of the gas delivered to RIGS at the point of interconnection shall not exceed the maximum allowable operating pressure ("MAOP") set forth in RIGS Operating Statement. E&Pco warrants that the quality of the gas that will flow through the Facilities will conform to the gas quality specifications of the RIGS Operating Statement. If gas delivered through the Facilities at any time fails to conform to any of the specifications set forth in RIGS Operating Statement, RIGS shall give notice to E&Pco of such nonconforming gas and may, in its discretion, immediately discontinue receiving gas at the Facilities until such nonconforming gas is remedied. E&Pco shall be liable for and pay all costs that the RIGS incurs as a result of any nonconforming gas and any penalties imposed on RIGS for any nonconforming gas. E&Pco shall be liable for and pay all costs arising from any damage caused by the nonconforming gas to RIGS's facilities or the facilities of third parties directly connected to RIGS. Failure to give such notice or discontinue service relating to nonconforming gas shall not constitute a waiver of RIGS's rights hereunder.

Governing Law: This Agreement, and all terms and provisions contained herein, and the respective obligations of the Parties are subject to valid laws, orders, rules, and regulations of duly constituted authorities having jurisdiction. This Agreement shall be governed by and interpreted in accordance with the laws of the state of Texas without regard to conflicts of law provisions . The Parties irrevocably submit to the exclusive jurisdiction of the state and federal courts located in Dallas, Texas in any action or proceeding arising out of or relating to this Agreement and waive any objection to such jurisdiction on the grounds that it is an inconvenient forum or any similar grounds.

10.

Assignment: This Agreement may not be assigned without prior written consent of the other Party, such consent not to be unreasonably withheld. All the terms, covenants and agreements hereof shall run in favor of and be binding upon the Parties hereto, their successors and assigns.

Page 4

11.

Term: This Agreement shall extend from the date of full execution hereof until the Facilities are removed, disconnected, or abandoned . The indemnification provisions, however, shall survive any termination hereof.

12.

Entire Agreement: This Agreement contains the entire agreement between the Parties and except as stated herein there are no oral promises, agreemnts or warranties affecting it.

13.

Waiver: The failure of either Party hereto at any time to require performance by the other Party of any provision hereof shall in no way affect the right of such Party thereafter to enforce the same, nor shall the waiver by any Party hereto of any breach of any provision hereof by the other Party be taken or held to be a waiver by such Party of any succeeding breach of such provision, or as a waiver of the provisions itself.

If you are in agreement with the foregoing please so indicate by signing and returning one copy of this Facility Construction and Reimbursement Agreement along with payment of the Estimate.

Sincerely,

REGENCY INTRASTATE GAS LP

By: RIGS GP LLC, its general partner

By: RIGS Haynesville Partnership Co., its sole member

L. Patric

Executive Vice President

Agreed To and Accepted

This 26 day of January, 2010

E&Pco, LLC

By:	/s/ Charles E. Edwards	By:	/s/ Osman Kaldirim
Name:	Charles E. Edwards	Name:	Osman Kaldirim, Jr.
Title:	EC Member	Title:	Vice President

Page 5

EXHIBIT A

Facility Construction and Reimbursement Agreement

Between

Regency Intrastate Gas LP ("RIGS") and E&Pco, LLC ( "E&Pco")

RESPONSIBILITY MATRIX

DESCRIPTION	OWN	DESIGN/INSTALL	OPERATE	MAINTAIN

Interconnect Site	RIGS	RIGS	RIGS	RIGS

Regency Intrastate Hot Tap(s)	RIGS	RIGS	RIGS	RIGS

Connecting Pipeline/Lateral {If required)RIGS taps to Meter Station Outlet	RIGS	RIGS	RIGS	RIGS

Meter (Custody Transfer)	RIGS	RIGS	RIGS	RIGS

EFM(Including Gas Chromatograph, Moisture Analyzer & H2S Monitor)	RIGS	RIGS	RIGS	RIGS

Flow Control Valve	RIGS	RIGS	RIGS	RIGS

OPP Valve	RIGS	RIGS	RIGS	RIGS

Filter-Separator/Coalescer	E&Pco	E&Pco	E&Pco	E&Pco

Connecting Pipeline/Lateral TBD taps to Meter Station Inlet	E&Pco	E&Pco	E&Pco	E&Pco

Site prep.Fencing,& Lighting	RIGS	RIGS	RIGS	RIGS

AC power, Telephone	E&Pco	E&Pco	E&Pco	E&Pco

Base Contract for Sale and Purchase of Natural Gas

This Base Contract is entered into as of the following date: November 20, 2009

The parties to this Base Contract are the following:

PARTY A Regency Gas Marketing LLC		PARTY NAME	PARTY B E & P Co., LLC
2001 Bryan Street, Suite 3700, Dallas, TX 76201		ADDRESS	255600 Tanglewllde Ste 460 Houston, TX 77063
www.regencvgas.com		BUSINESS WEBSITE
7238		CONTRACT NUMBER
61-0432754		D-U-N-S® NUMBER
x US FEDERAL: ¨ OTHER:	20-1005447	TAX ID NUMBERS	x US FEDERAL: ¨ OTHER:	20-2815319
DELAWARE		JURISDICTION OF ORGANIZATION	TEXAS
¨ Corporation ¨ Limited Partnership ¨ LLP	x LLC ¨ Partnership ¨ Other ___________	COMPANY TYPE	¨ Corporation ¨ Limited Partnership ¨ LLP	x LLC ¨ Partnership ¨ Other: ________________
		GUARANTOR (IF APPLICABLE)
CONTACT INFORMATION

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Jacque Wolf

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· COMMERCIAL

ATTN:

TEL#: Fax#:

EMAIL:

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Gas Scheduling

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· SCHEDULING

ATTN:

TEL#: Fax#:

EMAIL:

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Contract Administration

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· CONTRACT AND
LEGAL NOTICES

ATTN:

TEL#: Fax#:

EMAIL:

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Credit Manager

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· CREDIT

ATTN:

TEL#: Fax#:

EMAIL:

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Jacque Wolf

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· TRANSACTION
CONFIRMATIONS

ATTN:

TEL#: Fax#:

EMAIL:

ACCOUNTING INFORMATION

2001 Bryan Street, Suite 3700, Dallas, TX 75201

ATTN: Plant Accounting

TEL#: 214-750-1771 Fax#: 214-750-1749

EMAIL:

· INVOICES

· PAYMENTS

· SETTLEMENTS

ATTN:

TEL#: Fax#:

EMAIL:

BANK: JPMorgan Chase Bank

ABA: #021000021 ACCT: 713449486

OTHER DETAILS: For Credit to Regency Gas Services

WIRE TRANSFER
NUMBERS

(IF APPLICABLE)

BANK:

ABA: ACCT:

OTHER DETAILS: For Credit to:

BANK:

ABA: ACCT:

OTHER DETAILS:

ACH NUMBERS
(IF APPLICABLE)

BANK:

ABA: ACCT:

OTHER DETAILS:

ATTN:

ADDRESS:

CHECKS

(IF APPLICABLE)

ATTN:

ADDRESS:

Base Contract for Sale and Purchase of Natural Gas

(Continued)

This Base Contract incorporates by reference for all purposes the General Terms and Conditions for Sale and Purchase of Natural Gas published by the North American Energy Standards Board. The parties hereby agree to the following provisions offered in said General Terms and Conditions. In the event the parties fail to check a box, the specified default provision shall apply. Select the appropriate box(es) from each section:

Section 1.2

Transaction

Procedure

¨ Oral (default)

S Written

Section 10.2

Additional

Events of

Default

x No Additional Events of Default (default)

¨ Indebtedness Cross Default

¨ Party A:

¨ Party B:

¨ Transactional Cross Default

_______________________

Section 2.7

Confirm Deadline

x 2 Business Days after receipt (default)

¨ _____ Business Days after receipt

Section 2.8

Confirming Party

x Seller (default)

¨ Buyer

£ ___________________________________

Section 3.2

Performance

Obligation

x Cover Standard (default)

¨ Spot Price Standard

Section 10.3.1

Early

Termination

Damages

¨ Early Termination Damages Apply (default)

x Early Termination Damages Do Not Apply

Note: The following Spot Price Publication applies to both of the immediately preceding.

Section 10.3.2

Other

Agreement

Setoffs

¨ Other Agreement Setoffs Apply (default)

¨ Bilateral (default)

¨ Triangular

x Other Agreement Setoffs Do Not Apply

Section 2.31

Spot Price

Publication

x Gas Dally Midpoint (default)

¨ __________________________________

Section 6

Taxes

x Buyer Pays At and After Delivery Point (default)

¨ Seller Pays Before and At Delivery Point

Section 7.2

Payment Date

x 25^thDay of Month following Month of delivery (default)

£ Day of Month following Month of delivery

Section 15.5

Choice Of Law

Texas

Section 7.2

Method of Payment

x Wire transfer (default)

¨ Automated Clearinghouse Credit (ACH)

¨ Check

Section 15.10

Confidentiality

x Confidentiality applies (default)

¨ Confidentiality does not apply

Section 7.7

Netting

x Netting applies (default)

£ Netting does not apply

x Special Provisions Number of sheets attached: Two (2) Pages

¨ Addendum(s): _______________

IN WITNESS WHEREOF, the parties hereto have executed this Base Contract in duplicate.

Regency Gas Marketing.LLC	PARTY NAME	E & P Co., LLC
By: /s/ Pat Giroir	SIGNATURE	By: /s/ Charles E. Edwards
Pat Giroir	PRINTED NAME	Charles E. Edwards, Member/Manager
Vice President of Regency OLP GP LLC, the general partner of Regency Gas Services LP, the sola member of Regency Gas Marketing LLC	TITLE	By: /s/ Osman Kaldirim Osman Kaldirim, Jr., Member/Manager

Page 2 of 13

NAESB Standard 6.3.1
September 5, 2006

General Terms and Conditions

Base Contract for Sale and Purchase of Natural Gas

SECTION 1. PURPOSE AND PROCEDURES

1.1. These General Terms and Conditions are intended to facilitate purchase and sale transactions of Gas on a Firm or Interruptible basis. “Buyer’’ refers to the party receiving Gas and “Seller” refers to the party delivering Gas. The entire agreement between the parties shall be the Contract as defined in Section 2.9.

The parties have selected either the “Oral Transaction Procedure” or the “Written Transaction Procedure” as indicated on the Base Contract.

Oral Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Any Gas purchase and sale transaction may be effectuated in an EDI transmission or telephone conversation with the offer and acceptance constituting the agreement of the parties. The parties shall be legally bound from the time they so agree to transaction terms and may each rely thereon. Any such transaction shall be considered a “writing” and to have been “signed”. Notwithstanding the foregoing sentence, the parties agree that Confirming Party shall, and the other party may, confirm a telephonic transaction by sending the other party a Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means within three Business Days of a transaction covered by this Section 1.2 (Oral Transaction Procedure) provided that the failure to send a Transaction Confirmation shall not invalidate the oral agreement of the parties. Confirming Party adopts its confirming letterhead, or the like, as its signature on any Transaction Confirmation as the identification and authentication of Confirming Party. If the Transaction Confirmation contains any provisions other than those relating to the commercial terms of the transaction (i.e., price, quantity, performance obligation, delivery point, period of delivery and/or transportation conditions), which modify or supplement the Base Contract or General Terms and Conditions of this Contract (e.g., arbitration or additional representations and warranties), such provisions shall not be deemed to be accepted pursuant to Section 1.3 but must be expressly agreed to by both parties; provided that the foregoing shall not invalidate any transaction agreed to by the parties.

Written Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Should the parties come to an agreement regarding a Gas purchase and sale transaction for a particular Delivery Period, the Confirming Party shall, and the other party may, record that agreement on a Transaction Confirmation and communicate such Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means, to the other party by the close of the Business Day following the date of agreement. The parties acknowledge that their agreement will not be binding until the exchange of nonconflicting Transaction Confirmations or the passage of the Confirm Deadline without objection from the receiving party, as provided in Section 1.3.

1.3. If a sending party’s Transaction Confirmation is materially different from the receiving party’s understanding of the agreement referred to in Section 1.2, such receiving party shall notify the sending party via facsimile, EDI or mutually agreeable electronic means by the Confirm Deadline, unless such receiving party has previously sent a Transaction Confirmation to the sending party. The failure of the receiving party to so notify the sending party in writing by the Confirm Deadline constitutes the receiving party’s agreement to the terms of the transaction described in the sending party’s Transaction Confirmation. If there are any material differences between timely sent Transaction Confirmations governing the same transaction, then neither Transaction Confirmation shall be binding until or unless such differences are resolved including the use of any evidence that clearty resolves the differences in the Transaction Confirmations. In the event of a conflict among the terms of (i) a binding Transaction Confirmation pursuant to Section 1.2, (ii) the oral agreement of the parties which may be evidenced by a recorded conversation, where the parties have selected the Oral Transaction Procedure of the Base Contract, (iii) the Base Contract, and (iv) these General Terms and Conditions, the terms of the documents shall govern in the priority listed in this sentence.

1.4. The parties agree that each party may electronically record all telephone conversations with respect to this Contract between their respective employees, without any special or further notice to the other party. Each party shall obtain any necessary consent of its agents and employees to such recording. Where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, the parties agree not to contest the validity or enforceability of telephonic recordings entered into in accordance with the requirements of this Base Contract.

SECTION 2. DEFINITIONS

The terms set forth below shall have the meaning ascribed to them below. Other terms are also defined elsewhere in the Contract and shall have the meanings ascribed to them herein.

2.1. “Additional Event of Default” shall mean Transactional Cross Default or Indebtedness Cross Default, each as and if selected by the parties pursuant to the Base Contract.

2.2. “Affiliate” shall mean, 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 at least 50 percent of the voting power of the entity or person.

Page 3 of 13

NAESB Standard 6.3.1
September 5, 2006

2.3. “Alternative Damages” shall mean such damages, expressed in dollars or dollars per MMBtu, as the parties shall agree upon in the Transaction Confirmation, in the event either Seller or Buyer fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer.

2.4. “Base Contract” shall mean a contract executed by the parties that incorporates these General Terms and Conditions by reference; that specifies the agreed selections of provisions contained herein; and that sets forth other information required herein and any Special Provisions and addendum(s) as identified on page one.

2.5. “British thermal unit” or “Btu” shall mean the International BTU, which is also called the Btu (IT).

2.6. “Business Day(s)” shall mean Monday through Friday, excluding Federal Banking Holidays for transactions in the U.S.

2.7. “Confirm Deadline” shall mean 5:00 p.m. in the receiving party’s time zone on the second Business Day following the Day a Transaction Confirmation is received or, if applicable, on the Business Day agreed to by the parties in the Base Contract; provided, if the Transaction Confirmation is time stamped after 5:00 p.m. in the receiving party’s time zone, it shall be deemed received at the opening of the next Business Day.

2.8. “Confirming Party” shall mean the party designated in the Base Contract to prepare and forward Transaction Confirmations to the other party.

2.9. “Contract” shall mean the legally-binding relationship established by (i) the Base Contract, (ii) any and all binding Transaction Confirmations and (iii) where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, any and all transactions that the parties have entered into through an EDI transmission or by telephone, but that have not been confirmed in a binding Transaction Confirmation, all of which shall form a single integrated agreement between the parties.

2.10. “Contract Price” shall mean the amount expressed in U.S. Dollars per MMBtu to be paid by Buyer to Seller for the purchase of Gas as agreed to by the parties in a transaction.

2.11. “Contract Quantity” shall mean the quantity of Gas to be delivered and taken as agreed to by the parties in a transaction.

2.12. “Cover Standard”, as referred to in Section 3.2, shall mean that if there is an unexcused failure to take or deliver any quantity of Gas pursuant to this Contract, then the performing party shall use commercially reasonable efforts to (i) if Buyer is the performing party, obtain Gas, (or an alternate fuel if elected by, Buyer and replacement Gas is not available), or (ii) if Seller is the performing party, sell Gas, in either case, at a price reasonable for the delivery or production area, as applicable, consistent with: the amount of notice provided by the nonperforming party; the immediacy of the Buyer’s Gas consumption needs or Seller’s Gas sales requirements, as applicable; the quantities involved; and the anticipated length of failure by the nonperforming party.

2.13. “Credit Support Obligation(s)” shall mean any obligation(s) to provide or establish credit support for, or on behalf of, a party to this Contract such as cash, an irrevocable standby letter of credit, a margin agreement, a prepayment, a security interest in an asset, guaranty, or other good and sufficient security of a continuing nature.

2.14. “Day” shall mean a period of 24 consecutive hours, coextensive with a “day” as defined by the Receiving Transporter in a particular transaction.

2.15. “Delivery Period” shall be the period during which deliveries are to be made as agreed to by the parties in a transaction.

2.16. “Delivery Point(s)” shall mean such point(s) as are agreed to by the parties in a transaction.

2.17. “EDI” shall mean an electronic data interchange pursuant to an agreement entered into by the parties, specifically relating to the communication of Transaction Confirmations under this Contract.

2.18. “EFP” shall mean the purchase, sale or exchange of natural Gas as the “physical” side of an exchange for physical transaction involving gas futures contracts. EFP shall incorporate the meaning and remedies of “Firm”, provided that a party’s excuse for nonperformance of its obligations to deliver or receive Gas will be governed by the rules of the relevant futures exchange regulated under the Commodity Exchange Act.

2.19. “Firm” shall mean that either party may interrupt its performance without liability only to the extant that such performance is prevented for reasons of Force Majeure; provided, however, that during Force Majeure interruptions, the party invoking Force Majeure may be responsible for any Imbalance Charges as set forth in Section 4.3 related to its interruption alter the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by the Transporter.

2.20. “Gas” shall mean any mixture of hydrocarbons and noncombustible gases in a gaseous state consisting primarily of methane.

2.21. “Guarantor shall mean any entity that has provided a guaranty of the obligations of a party hereunder.

2.22. “Imbalance Charges” shall mean any fees, penalties, costs or charges (in cash or in kind) assessed by a Transporter for failure to satisfy the Transporter’s balance and/or nomination requirements.

2.23. “Indebtedness Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it or its Guarantor, if any, experiences a default, or similar condition or event however therein defined, under one or more agreements or instruments, individually or collectively, relating to indebtedness (such indebtedness to include any obligation whether present or future, contingent or otherwise, as principal or surety or otherwise) for the payment or repayment of borrowed money in an aggregate amount greater than the threshold specified in the Base Contract with respect to such party or its Guarantor, if any, which results in such indebtedness becoming immediately due and payable.

Page 4 of 13

NAESB Standard 6.3.1
September 5, 2006

2.24. “Interruptible” shall mean that either party may interrupt its performance at any time for any reason, whether or not caused by an event of Force Majeure, with no liability, except such interrupting party may be responsible for any Imbalance Charges as set forth in Section 4.3 related to its interruption after the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by Transporter.

2.25. “MMBtu” shall mean one million British thermal units, which is equivalent to one dekatherm.

2.26. “Month” shall mean the period beginning on the first Day of the calendar month and ending immediately prior to the commencement of the first Day of the next calendar month.

2.27. “Payment Date” shall mean a date, as indicated on the Base Contract, on or before which payment is due Seller for Gas received by Buyer in the previous Month.

2.28. “Receiving Transporter” shall mean the Transporter receiving Gas at a Delivery Point, or absent such receiving Transporter, the Transporter delivering Gas at a Delivery Point.

2.29. “Scheduled Gas” shall mean the quantity of Gas confirmed by Transporter(s) for movement, transportation or management.

2.30. “Specified Transaction(s)” shall mean any other transaction or agreement between the parties for the purchase, sale or exchange of physical Gas, and any other transaction or agreement identified as a Specified Transaction under the Base Contract.

2.31. “Spot Price” as referred to in Section 3.2 shall mean the price listed in the publication indicated on the Base Contract, under the listing applicable to the geographic location closest in proximity to the Delivery Point(s) for the relevant Day; provided, if there is no single price published for such location for such Day, but there is published a range of prices, then the Spot Price shall be the average of such high and low prices. If no price or range of prices is published for such Day, then the Spot Price shall be the average of the following: (i) the price (determined as stated above) for the first Day for which a price or range of prices is published that next precedes the relevant Day; and (ii) the price (determined as stated above) for the first Day for which a price or range of prices is published that next follows the relevant Day.

2.32. “Transaction Confirmation” shall mean a document, similar to the form of Exhibit A, setting forth the terms of a transaction formed pursuant to Section 1 for a particular Delivery Period.

2.33. “Transactional Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it shall be in default, however therein defined, under any Specified Transaction.

2.34. “Termination Option” shall mean the option of either party to terminate a transaction in the event that the other party fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer, for a designated number of days during a period as specified on the applicable Transaction Confirmation.

2.35. “‘Transporter(s)” shall mean all Gas gathering or pipeline companies, or local distribution companies, acting in the capacity of a transporter, transporting Gas for Seller or Buyer upstream or downstream, respectively, of the Delivary Point pursuant to a particular transaction.

SECTION 3. PERFORMANCE OBLIGATION

3.1. Seller agrees to sell and deliver, and Buyer agrees to receive and purchase, the Contract Quantity for a particular transaction in accordance with the terms of the Contract Sales and purchases will be on a Firm or Interruptible basis, as agreed to by the parties in a transaction.

The parties have selected either the “Cover Standard” or the “Spot Price Standard” as indicated on the Base Contract.

Cover Standard:

3.2. The sole and exclusive remedy of the parties in the event of a breach of a Firm obligation to deliver or receive Gas shall be recovery of the following: (i) in the event of a breach by Seller on any Day(s), payment by Seller to Buyer in an amount equal to the positive difference, if any, between the purchase price paid by Buyer utilizing the Cover Standard and the Contract Price, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantify actually delivered by Seller for such Day(s) excluding any quantity for which no replacement is available; or (ii) in the event of a breach by Buyer on any Day(s), payment by Buyer to Seller in the amount equal to the positive difference, if any, between the Contract Price and the price received by Seller utilizing the Cover Standard for the resale of such Gas, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantity actually taken by Buyer for such Day(s) excluding any quantity for which no sale is available; and (iii) in the event that Buyer has used commercially reasonable efforts to replace the Gas or Seller has used commercially reasonable efforts to sell the Gas to a third party, and no such replacement or sale is available for all or any portion of the Contract Quantity of Gas, then in addition to (i) or (ii) above, as applicable, the sole and exclusive remedy of the performing party with respect to the Gas not replaced or sold shall be an amount equal to any unfavorable difference between the Contract Price and the Spot Price, adjusted for such transportation to the applicable Delivery Point, multiplied by the quantity of such Gas not replaced or sold. Imbalance Charges shall not be recovered under this Section 3.2, but Seller and/or Buyer shall be responsible for Imbalance Charges, if any, as provided in Section 4.3. The amount of such unfavorable difference shall be payable five Business Days after presentation of the performing party’s invoice, which shall set forth the basis upon which such amount was calculated.

Page 5 of 13

NAESB Standard 6.3.1
September 5, 2006

Spot Price Standard:

3.3. Notwithstanding Section 3.2, the parties may agree to Alternative Damages in a Transaction Confirmation executed in writing by both parties.

3.4. In addition to Sections 3.2 and 3.3, the parties may provide for a Termination Option in a Transaction Confirmation executed in writing by both parties. The Transaction Confirmation containing the Termination Option will designate the length of nonperformance triggering the Termination Option and the procedures for exercise thereof, how damages for nonperformance will be compensated, and how liquidation costs will be calculated.

SECTION 4. Transportation, nominations, and imbalances

4.1. Seller shall have the sole responsibility for transporting the Gas to the Delivery Point(s). Buyer shall have the sole responsibility for transporting the Gas from the Delivery Point(s).

4.2. The parties shall coordinate their nomination activities, giving sufficient time to meet the deadlines of the affected Transporters). Each party shall give the other party timely prior Notice, sufficient to meet the requirements of all Transporters) involved in the transaction, of the quantities of Gas to be delivered arid purchased each Day. Should either party become aware that actual deliveries at the Delivery Point(s) are greater or lesser than the Scheduled Gas, such party shall promptly notify the other party.

4.3. The parties shall use commercially reasonable efforts to avoid imposition of any Imbalance Charges. If Buyer or Seller receives an invoice from a Transporter that includes Imbalance Charges, the parties shall determine the validity as well as the cause of such Imbalance Charges. If the Imbalance Charges were,incurred as a result of Buyer’s receipt of quantities of Gas greater than or less than the Scheduled Gas, then Buyer shall pay for such Imbalance Charges or reimburse Seller for such Imbalance Charges paid by Seller, If the Imbalance Charges were incurred as a result of Seller’s delivery of quantities of Gas greater than or less than the Scheduled Gas, then Seller shall pay for such Imbalance Charges or reimburse Buyer for such Imbalance Charges paid by Buyer.

SECTION 5. QUALITY AND MEASUREMENT

All Gas delivered by Seller shall meet the pressure, quality and heat content requirements of the Receiving Transporter. The unit of quantity measurement for purposes of this Contract shall be one MMBtu dry. Measurement of Gas quantities hereunder shall be in accordance with the established procedures of the Receiving Transporter.

SECTION 6. TAXES

The parties have selected either “Buyer Pays At and After Delivery Point” or “Seller Pays Before and At Delivery Point” as indicated on the Base Contract.

Buyer Pays At and After Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas at the Delivery Point(s) and all Taxes after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or changes shall furnish the other party any necessary documentation thereof.

Seller Pays Before and At Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s) and all Taxes at the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or charges shall furnish the other party any necessary documentation thereof.

SECTION 7. BILLING, PAYMENT, AND AUDIT

7.1. Seller shall invoice Buyer for Gas delivered and received in the preceding Month and for any other applicable charges, providing supporting documentation acceptable in industry practice to support the amount charged. If the actual quantity delivered is not known by the billing date, billing will be prepared based on the quantity of Scheduled Gas. The invoiced quantity will then be adjusted to the actual quantity on the following Month’s billing or as soon thereafter as actual delivery information is available.

Page 6 of 13

NAESB Standard 6.3.1
September 5, 2006

7.2. Buyer shall remit the amount due under Section 7.1 in the manner specified in the Base Contract, in immediately available funds, on or before the later of the Payment Date or 10 Days after receipt of the invoice by Buyer; provided that if the Payment Date is not a Business Day, payment is due on the next Business Day following that date. In the event any payments are due Buyer hereunder, payment to Buyer shall be made in accordance with this Section 7.2.

7.3. In the event payments become due pursuant to Sections 3.2 or 3.3, the performing party may submit an invoice to the nonperforming party for an accelerated payment setting forth the basis upon which the invoiced amount was calculated. Payment from the nonperforming party will be due five Business Days after receipt of invoice.

7.4. If the invoiced party, in good faith, disputes the amount of any such invoice or any part thereof, such invoiced party will pay such amount as it concedes to be correct; provided, however, if the invoiced party disputes the amount due, it must provide supporting documentation acceptable in industry practice to support the amount paid or disputed without undue delay. In the event the parties are unable to resolve such dispute, either party may pursue any remedy available at law or in equity to enforce its rights pursuant to this Section.

7.5. If the invoiced party fails to remit the full amount payable when due, interest on the unpaid portion shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under “Money Rates” by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

7.6. A party shall have the right, at its own expense, upon reasonable Notice and at reasonable times, to examine and audit and to obtain copies of the relevant portion of the books, records, and telephone recordings of the other party only to the extent reasonably necessary to verify the accuracy of any statement, charge, payment, or computation made under the Contract. This right to examine, audit, and to obtain copies shall not be available with respect to proprietary information not directly relevant to transactions under this Contract. All invoices and billings shall be conclusively presumed final and accurate and all associated claims for under- or overpayments shall be deemed waived unless such invoices or billings are objected to in writing, with adequate explanation and/or documentation, within two years after the Month of Gas delivery. All retroactive adjustments under Section 7 shall be paid in full by the party owing payment within 30 Days of Notice and substantiation of such inaccuracy.

7.7. Unless the parties have elected on the Base Contract not to make this Section 7.7 applicable to this Contract, the parties shall net all undisputed amounts due and owing, and/or past due, arising under the Contract such that the party owing the greater amount shall make a single payment of the net amount to the other party in accordance with Section 7; provided that no payment required to be made pursuant to the terms of any Credit Support Obligation or pursuant to Section 7.3 shall be subject to netting under this Section. If the parties have executed a separate netting agreement, the terms and conditions therein shall prevail to the extent inconsistent herewith.

SECTION 8. TITLE, WARRANTY, AND INDEMNITY

8.1. Unless otherwise specifically agreed, title to the Gas shall pass from Seller to Buyer at the Delivery Point(s). Seller shall have responsibility for and assume any liability with respect to the Gas prior to its delivery to Buyer at the specified Delivery Point(s). Buyer shall have responsibility for and assume any liability with respect to said Gas after its delivery to Buyer at the Delivery Point(s).

8.2. Seller warrants that it will have the right to convey and will transfer good and merchantable title to all Gas sold hereunder and delivered by it to Buyer, free and clear of all liens, encumbrances, and claims. EXCEPT AS PROVIDED IN THIS SECTION 8.2 AND IN SECTION 15.8. ALL OTHER WARRANTIES, EXPRESS OR IMPLIED, INCLUDING ANY WARRANTY OF MERCHANTABILITY OR OF FITNESS FOR ANY PARTICULAR PURPOSE, ARE DISCLAIMED.

8.3. Seller agrees to indemnify Buyer and save it harmless from all losses, liabilities or claims including reasonable attorneys’ fees and costs of court (“Claims”), from any and all persons, arising from or out of claims of title, personal injury (including death) or properly damage from said Gas or other charges thereon which attach before title passes to Buyer. Buyer agrees to indemnify Seller and save it harmless from all Claims, from any and all persons, arising from or out of claims regarding payment, personal injury (including death) or property damage from said Gas or other charges thereon which attach after title passes to Buyer.

8.4. The parties agree that the delivery of and the transfer of title to all Gas under this Contract shall take place within the Customs Territory of the United States (as defined in general note 2 of the Harmonized Tariff Schedule of the United States 19 U.S.C. §1202, General Notes, page 3); provided, however, that in the event Seller took title to the Gas outside the Customs Territory of the United States, Seller represents and warrants that it is the importer of record for all Gas entered and delivered into the United States, and shall be responsible for entry and entry summary filings as well as the payment of duties, taxes and fees, if any, and all applicable record keeping requirements.

8.5. Notwithstanding the other provisions of this Section 8, as between Seller and Buyer, Seller will be liable for all Claims to the extent that such arise from the failure of Gas delivered by Seller to meet the quality requirements of Section 5.

SECTION 9. NOTICES

9.1. All Transaction Confirmations, invoices, payment instructions, and other communications made pursuant to the Base Contract (“Notices”) shall be made to the addresses specified in writing by the respective parties from time to time.

9.2. All Notices required hereunder shall be in writing and may be sent by facsimile or mutually acceptable electronic means, a nationally recognized overnight courier service, first class mail or hand delivered.

9.3. Notice shall be given when received on a Business Day by the addressee. In the absence of proof of the actual receipt date, the following presumptions will apply. Notices sent by facsimile shall be deemed to have been received upon the sending party’s receipt of its facsimile machine’s confirmation of successful transmission. If the day on which such facsimile is received is not a Business Day or is after five p.m. on a Business Day, then such facsimile shall be deemed to have been received on the next following Business Day. Notice by overnight mail or courier shall be deemed to have been received on the next Business Day after it was sent or such earlier time as is confirmed by the receiving party. Notice via first class mail shall be considered delivered five Business Days after mailing.

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NAESB Standard 6.3.1
September 5, 2006

9.4. The party receiving a commercially acceptable Notice of change in payment instructions or other payment information shall not be obligated to implement such change until ten Business Days after receipt of such Notice.

SECTION 10. FINANCIAL RESPONSIBILITY

10.1. If either party (“X”) has reasonable grounds for insecurity regarding the performance of any obligation under this Contract (whether or not then due) by the other party (“Y”) (including, without limitation, the occurrence of a material change in the creditworthiness of Y or its Guarantor, if applicable), X may demand Adequate Assurance of Performance. “Adequate Assurance of Performance” shall mean sufficient security in the form, amount, for a term, and from an issuer, all as reasonably acceptable to X, including, but not limited to cash, a standby irrevocable letter of credit, a prepayment, a security interest in an asset or guaranty. Y hereby grants to X a continuing first priority security interest in, lien on, and right of setoff against all Adequate Assurance of Performance in the form of cash transferred by Y to X pursuant to this Section 10.1. Upon the return by X to Y of such Adequate Assurance of Performance, the security interest and lien granted hereunder on that Adequate Assurance of Performance shall be released automatically and, to the extent possible, without any further action by either party.

10.2. In the event (each an “Event of Default”) either party (the “Defaulting Party”) or its Guarantor shall: (i) make an assignment or any general arrangement for the benefit of creditors; (ii) file a petition or otherwise commence, authorize, or acquiesce in the commencement of a proceeding or case under any bankruptcy or similar law for the protection of creditors or have such petition filed or proceeding commenced against it; (iii) otherwise become bankrupt or insolvent (however evidenced); (iv) be unable to pay its debts as they fall due; (v) have a receiver, provisional liquidator, conservator, custodian, trustee or other similar official appointed with respect to it or substantially all of its assets; (vi) fail to perform any obligation to the other party with respect to any Credit Support Obligations relating to the Contract; (vii) fail to give Adequate Assurance of Performance under Section 10.1 within 48 hours but at least one Business Day of a written request by the other party; (viii) not have paid any amount due the other party hereunder on or before the second Business Day following written Notice that such payment is due; or ix) be the affected party with respect to any Additional Event of Default; then the other party (the “Non-Defaulting Party”) shall have the right, at its sole election, to immediately withhold and/or suspend deliveries or payments upon Notice and/or to terminate and liquidate the transactions under the Contract, in the manner provided in Section 10.3, in addition to any and all other remedies available heraunder.

10.3. If an Event of Default has occurred and is continuing, the Non-Defaulting Party shall have the right, by Notice to the Defaulting Party, to designate a Day, no, earlier than the Day such Notice is given_:and no later than 20 Days after such Notice is given, as an early termination date (the “Early Termination Date”) for the liquidation and termination pursuant to Section 10.3.1 of all transactions under the Contract, each a “Terminated Transaction”. On the Early Termination Date, all transactions will terminate, other than those transactions, if any, that may not be liquidated and terminated under applicable law (“Excluded Transactions”); which Excluded Transactions must be liquidated and terminated as soon thereafter as is legally permissible, and upon termination shall be a Terminated Transaction and be valued consistent with Section 10.3.1 below. With respect to each Excluded Transaction, its actual termination date shall be the Early Termination Date for purposes of Section 10.3.1.

The parties have selected either “Early Termination Damages Apply” or “Early Termination Damages Do Not Apply” as indicated on the Base Contract.

Early Termination Damages Apply:

10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, (i) the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section 3.2), for which payment has not yet been made by the party that owes such payment under this Contract and (ii) the Market Value, as defined below, of each Terminated Transaction. The Non-Defaulting Party shall (x) liquidate and accelerate each Terminated Transaction at its Market Value, so that each amount equal to the difference between such Market Value and the Contract Value, as defined below, of such Terminated Transaction(s) shall be due to the Buyer under the Terminated Transaction(s) if such Market Value exceeds the Contract Value and to the Seller if the opposite is the case; end (y) where appropriate, discount each amount then due under clause (x) above to present value in a commercially reasonable manner as of the Early Termination Date (to take account of the period between the date of liquidation and the date on which such amount would have otherwise been due pursuant to the relevant Terminated Transactions).

For purposes of this Section 10.3.1, “Contract Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the Contract Price, and “Market Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the market price for a similar transaction at the Delivery Point determined by the Non-Defaulting Party in a commercially reasonable manner. To ascertain the Market Value, the Non-Defaulting Party may consider, among other valuations, any or all of the settlement prices of NYMEX Gas futures contracts, quotations from leading dealers in energy swap contracts or physical gas trading markets, similar sales or purchases and any other bona fide third-party offers, all adjusted for the length of the term and differences in transportation costs. A party shall not be required to enter into a replacement transaction(s) in order to determine the Market Value. Any extension(s) of the term of a transaction to which parties are not bound as of the Early Termination Date (including but not limited to “evergreen provisions”) shall not be considered in determining Contract Values and Market Values. For the avoidance of doubt, any option pursuant to which one party has the right to extend the term of a transaction shall be considered in determining Contract Values and Market Values. The rate of interest used in calculating net present value shall be determined by the Non-Defaulting Party in a commercially reasonable manner.

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NAESB Standard 6.3.1
September 5, 2006

Early Termination Damages Do Not Apply:

10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section 3.2), for which payment has not yet been made by the party that owes such payment under this Contract.

The parties have selected either “Other Agreement Setoffs Apply” or “Other Agreement Setoffs Do Not Apply” as indicated on the Base Contract.

Other Agreement Setoffs Apply:

Bilateral Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff any Net Settlement Amount against (i) any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; and (ii) any amount(s) (including any excess cash margin or excess cash collateral) owed or held by the party that is entitled to the Net Settlement Amount under any other agreement or arrangement between the parlies.

Triangular Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option, and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff (i) any Net Settlement Amount against any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; (ii) any Net Settlement Amount against any amount(s)’ (including any excess cash margin or excess cash collateral) owed by or to a party under any other agreement or arrangement between the parties; (iii) any Net Settlement Amount owed to the Non-Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Non-Defaulting Party or its Affiliates to the Defaulting Party under any other agreement or arrangement; (iv) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party to the Non-Defaulting Party or its Affiliates under any other agreement or arrangement; and/or(v) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party or its Affiliates to the Non-Defaulting Party under any other agreement or arrangement.

Other Agreement Setoffs Do Not Apply:

10.3.3. If any obligation that is to be included in any netting, aggregation or setoff pursuant to Section 10.3.2 is unascertained, the Non-Defaulting Party may in good faith estimata that obligation and net, aggregate or setoff, as applicable, in respect of the estimate, subject to the Non-Defaulting Party, accounting to the Defaulting Party when the obligation is ascertained. Any amount not then due which is included in any netting, aggregation or setoff pursuant to Section 10.3.2 shall be discounted to net present value in a commercially reasonable manner determined by the Non-Defaulting Party.

10.4. As soon as practicable after a liquidation,’ Notice shall be given by the Non-Defaulting Party to the Defaulting Party of the Net Settlement Amount, and whether the Net Settlement Amount is due to or due from the Non-Defaulting Party. The Notice shall include a written statement explaining in reasonable detail the calculation of the Net Settlement Amount, provided that failure to give such Notice shall not affect the validity or enforceability of the liquidation or give rise to any claim by the Defaulting Party against the Non-Defaulting Party. The Net Settlement Amount as well as any setoffs applied against such amount pursuant to Section 10.3.2, shall be paid by the dose of business on the second Business Day following such Notice, which date shall not be earlier than the Early Termination Date. Interest on any unpaid portion of the Net Settlement Amount as adjusted by setoffs, shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under “Money Rates” by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

10.5. The parties agree that the transactions hereunder constitute a “forward contract” within the meaning of the United States Bankruptcy Code and that Buyer and Seller are each “forward contract merchants” within the meaning of the United States Bankruptcy Code.

10.6. The Non-Defaulting Party’s remedies under this Section 10 are the sole and exclusive remedies of the Non-Defaulting Party with resped to the occurrence of any Earty Termination Date. Each party reserves to itself all other rights, setoffs, counterclaims and other defenses that it is or may be entitled to arising from the Contract.

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NAESB Standard 6.3.1
September 5, 2006

10.7. With respect to this Section 10, if the parties have executed a separate netting agreement with close-out netting provisions, the terms and conditions therein shall prevail to the extent inconsistent herewith.

SECTION 11. FORCE MAJEURE

11.1. Except with regard to a party’s obligation to make payment(s) due under Section 7, Section 10.4, and Imbalance Charges under Section 4, neither party shall be liable to the other for failure to perform a Firm obligation, to the extent such failure was caused by Force Majeure. The term “Force Majeure” as employed herein means any cause not reasonably within the control of the party claiming suspension, as further defined in Section 11.2.

11.2. Force Majeure shall include, but not be limited to, the following: (i) physical events such as acts of God, landslides, lightning, earthquakes, fires, storms or storm warnings, such as hurricanes, which result in evacuation of the affected area, floods, washouts, explosions, breakage or accident or necessity of repairs to machinery or equipment or lines of pipe; (ii) weather related events affecting an entire geographic region, such as low temperatures which cause freezing or failure of wells or lines of pipe; (iii) interruption and/or curtailment of Firm transportation and/or storage by Transporters; (iv) acts of others such as strikes, lockouts or other industrial disturbances, riots, sabotage, insurrections or wers, or acts of terror; and (v) governmental actions such as necessity for compliance with any court order, law, statute, ordinance, regulation, or policy having the effect of law promulgated by a governmental authority having jurisdiction. Seller and Buyer shall make reasonable efforts to avoid the adverse impacts of a Force Majeure and to resolve the event or occurrence once it has occurred in order to resume performance.

11.3. Neither party shall be entitled to the benefit of the provisions of Force Majeure to the extent performance is affected by any or all of the following circumstances: (i) the curtailment of interruptible or secondary Firm transportation unless primary, in-path, Firm transportation is also curtailed; (ii) the party claiming excuse failed to remedy the condition and to resume the performance of such covenants or obligations with reasonable dispatch; or (iii) economic hardship, to include, without limitation, Seller’s ability to sell Gas at a higher or more advantageous price than the Contract Price, Buyer’s ability to purchase Gas at a lower or more advantageous price than the Contract Price, or a regulatory agency disallowing, in whole or in part, the pass through of costs resulting from this Contract; (iv) the loss of Buyer’s market(s) or Buyer’s inability to use or resell Gas purchased hereunder, except, in either case, as provided in Section 11.2; or (v) the loss or failure of Seller’s gas supply or depletion of reserves, except, in either case, as provided in Section 11.2. The party claiming Force Majeure shall not be excused from its responsibility for Imbalance Charges.

11.4. Notwithstanding anything to the contrary herein, the parties agree that the settlement of strikes, lockouts or other industrial disturbances shall be within the sole discretion of the party experiencing such disturbance.

11.5. The party whose performance is prevented by Force Majeure must provide Notice to the other party. Initial Notice may be given orally; however, written Notice with reasonably full particulars of the event or occurrence is required as soon as reasonably possible. Upon providing written Notice of Force Majeure to the other party, the effected party will be relieved of its obligation, from the onset of the Force Majeure event, to make or accept delivery of Gas, as applicable, to the extent and for the duration of Force Majeure, and neither party shall be deemed to have failed in such obligations to the other during such occurrence or event.

11.6. Notwithstanding Sections 11.2 and 11.3, the parties may agree to alternative Force Majeure provisions in a Transaction Confirmation executed in writing by both parties.

SECTION 12. TERM

This Contract may be terminated on 30 Day’s written Notice, but shall remain in effect until the expiration of the latest Delivery Period of any transaction(s). The rights of either party pursuant to Section 7.6, Section 10, Section 13, the obligations to make payment hereunder, and the obligation of either party to indemnify the other, pursuant hereto shall survive the termination of the Base Contract or any transaction.

SECTION 13. LIMITATIONS

FOR BREACH OF ANY PROVISION FOR WHICH AN EXPRESS REMEDY OR MEASURE OF DAMAGES IS PROVIDED, SUCH EXPRESS REMEDY OR MEASURE OF DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY. A PARTY’S LIABILITY HEREUNDER SHALL BE LIMITED AS SET FORTH IN SUCH PROVISION, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. IF NO REMEDY OR MEASURE OF DAMAGES IS EXPRESSLY PROVIDED HEREIN OR IN A TRANSACTION, A PARTY’S LIABILITY SHALL BE LlMITED TO DIRECT ACTUAL DAMAGES ONLY. SUCH DIRECT ACTUAL DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. UNLESS EXPRESSLY HEREIN PROVIDED, NETHER PARTY SHALL BE LIABLE FOR CONSEQUENTIAL, INCIDENTAL, PUNITIVE, EXEMPLARY OR INDIRECT DAMAGES, LOST PROFITS OR OTHER BUSINESS INTERRUPTION DAMAGES, BY STATUTE, IN TORT OR CONTRACT, UNDER ANY INDEMNITY PROVISION OR OTHERWISE. IT IS THE INTENT OF THE PARTIES THAT THE LIMITATIONS HEREIN IMPOSED ON REMEDIES AND THE MEASURE OF DAMAGES BE WITHOUT REGARD TO THE CAUSE OR CAUSES RELATED THERETO, INCLUDING THE NEGLIGENCE OF ANY PARTY, WHETHER SUCH NEGLIGENCE BE SOLE, JOINT OR CONCURRENT, OR ACTIVE OR PASSIVE TO THE EXTENT ANY DAMAGES REQUIRED TO BE PAID HEREUNDER ARE LIQUIDATED, THE PARTIES ACKNOWLEDGE THAT THE DAMAGES ARE DIFFICULT OR IMPOSSIBLE TO DETERMINE, OR OTHERWISE OBTAINING AN ADEQUATE REMEDY IS INCONVENIENT AND THE DAMAGES CALCULATED HEREUNDER CONSTITUTE A REASONABLE APPROXIMATION OF THE HARM OR LOSS.

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NAESB Standard 6.3.1
September 5, 2006

SECTION 14. MARKET DISRUPTION

If a Market Disruption Event has occurred then the parties shall negotiate in good faith to agree on a replacement price for the Floating Price (or on a method for determining a replacement price for the Floating Price) for the affected Day, and if the parties have not so agreed on or before the second Business Day following the affected Day then the replacement price for the Floating Price shall be determined within the next two following Business Days with each party obtaining, in good faith and from non-affiliated market participants in the relevant market, two quotes for prices of Gas for the affected Day of a similar quality and quantity in the geographical location closest in proximity to the Delivery Point and averaging the four quotes. If either party fails to provide two quotes then the average of the other party’s two quotes shall determine the replacement price for the Floating Price. “Floating Price” means the price or a factor of the price agreed to in the transaction as being based upon a specified index. “Market Disruption Event” means, with respect to an index specified for a transaction, any of the following events: (a) the failure of the index to announce or publish information necessary for determining the Floating Price; (b) the failure of trading to commence or the permanent discontinuation or material suspension of trading on the exchange or market acting as the index; (c) the temporary or permanent discontinuance or unavailability of the index; (d) the temporary or permanent closing of any exchange acting as the index; or (e) both parties agree that a material change in the formula for or the method of determining the Floating Price has occurred. For the purposes of the calculation of a replacement price for the Floating Price, all numbers shall be rounded to three decimal places. If the fourth decimal number is five or greater, then the third decimal number shall be increased by one and if the fourth decimal number is less than five, then the third decimal number shall remain unchanged.

SECTION 15. MISCELLANEOUS

15.1. This Contract shall be binding upon and inure to the benefit of the successors, assigns, personal representatives, and heirs of the respective parties hereto, and the covenants, conditions, rights and obligations of this Contract shall run for the full term of this Contract. No assignment of this Contract, in whole or in part, will be made without the prior written consent of the non-assigning party (and shall not relieve the assigning party from liability hereunder), which consent will not be unreasonably withheld or delayed; provided, either party may (i) transfer, sell, pledge, encumber, or assign this Contract or the accounts, revenues, or proceeds hereof in connection with any financing or other financial arrangements, or (ii) transfer its interest to any parent or Affiliate by assignment, merger or otherwise without the prior approval of the other party. Upon any such assignment, transfer and assumption, the transferor shall remain principally liable for and shall not be relieved of or discharged from any obligations hereunder.

15.2. If any provision in this Contract is determined to be invalid, void or unenforceable by any court having jurisdiction, such determination shall not invalidate, void, or make unenforceable any other provision, agreement or covenant of this Contract.

15.3. No waiver of any breach of this Contract shall be held to be a waiver of any other or subsequent breach.

15.4. This Contract sets forth all understandings between the parties respecting each transaction subject hereto, and any prior contracts, understandings and representations, whether oral or written, relating to such transactions are merged into and superseded by this Contract and any effective transaction(s). This Contract may be amended only by a writing executed by both parties.

15.5. The interpretation and performance of this Contract shall be governed by the laws of the jurisdiction as indicated on the Base Contract, excluding, however, any conflict of laws rule which would apply the law of another jurisdiction.

15.6. This Contract and all provisions herein will be subject to all applicable and valid statutes, rules, orders and regulations of any governmental authority having jurisdiction over the parties, their facilities, or Gas supply, this Contract or transaction or any provisions thereof.

15.7. There is no third party beneficiary to this Contract.

15.8. Each party to this Contract represents and warrants that it has full and complete authority to enter into and perform this Contract. Each person who executes this Contract on behalf of either party represents and warrants that it has full and complete authority to do so and that such party will be bound thereby.

15.9. The headings and subheadings contained in this Contract are used solely for convenience and do not constitute a part of this Contract between the parties and shall not be used to construe or interpret the provisions of this Contract.

15.10. Unless the parties have elected on the Base Contract not to make this Section 15.10 applicable to this Contract, neither party shall disclose directly or indirectly without the prior written consent of the other party the terms of any transaction to a third party (other than the employees, lenders, royalty owners, counsel, accountants and other agents of the party, or prospective purchasers of all or substantially all of a party’s assets or of any rights under this Contract, provided such persons shall have agreed to keep such terms confidential) except (i) in order to comply with any applicable law, order, regulation, or exchange rule, (ii) to the extent necessary for the enforcement of this Contract, (iii) to the extent necessary to implement any transaction, (iv) to the extent necessary to comply with a regulatory agency’s reporting requirements including but not limited to gas cost recovery proceedings; or (v) to the extent such information is delivered to such third party for the sole purpose of calculating a published index. Each party shall notify the other party of any proceeding of which it is aware which may result in disclosure of the terms of any transaction (other than as permitted hereunder) and use reasonable efforts to prevent or limit the disclosure. The existence of this Contract is not subject to this confidentiality obligation. Subject to Section 13, the parties shall be entitled to all remedies available at law or in equity to enforce, or seek relief in connection with this confidentiality obligation. The terms of any transaction hereunder shall be kept confidential by the parties hereto for one year from the expiration of the transaction.

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NAESB Standard 6.3.1
September 5, 2006

In the event that disclosure is required by a governmental body or applicable law, the party subject to such requirement may disclose the material terms of this Contract to the extent so required, but shall promptly notify the other party, prior to disclosure, and shall cooperate (consistent with the disclosing party’s legal obligations) with the other party’s efforts to obtain protective orders or similar restraints with respect to such disclosure at the expense of the other party.

15.11. The parties may agree to dispute resolution procedures in Special Provisions attached to the Base Contract or in a Transaction Confirmation executed in writing by both parties.

15.12. Any original executed Base Contract, Transaction Confirmation or other related document may be digitally copied, photocopied, or stored on computer tapes and disks (the “Imaged Agreement”). The Imaged Agreement, if introduced as evidence on paper, the Transaction Confirmation, if introduced as evidence in automated facsimile form, the recording, if introduced as evidence in its original form, and all computer records of the foregoing, if introduced as evidence in printed format, in any judicial, arbitration, mediation or administrative proceedings will be admissible as between the parlies to the same extent and under the same conditions as other business records originated and maintained in documentary form. Neither Party shall object to the admissibility of the recording, the Transaction Confirmation, or the Imaged Agreement on the basis that such were not originated or maintained in documentary form. However, nothing herein shall be construed as a waiver of any other objection to the admissibility of such evidence.

DISCLAIMER: The purposes of this Contract are to facilitate trade, avoid misunderstandings and make more definite the terms of contracts of purchase and sale of natural gas. Further, NAESB does not mandate the use of this Contract by any party. NAESB DISCLAIMS AND EXCLUDES, AND ANY USER OF THIS CONTRACT ACKNOWLEDGES AND AGREES TO NAESB’S DISCLAIMER OF, ANY AND ALL WARRANTIES, CONDITIONS OR REPRESENTATIONS, EXPRESS OR IMPLIED, ORAL OR WRITTEN, WTTH RESPECT TO THIS CONTRACT OR ANY PART THEREOF, INCLUDING ANY AND ALL IMPLIED WARRANTIES OR CONDITlONS OF TTTLE, NON-INFRINGEMENT, MERCHANTABILITY, OR FITNESS OR SUITABILITY FOR ANY PARTICULAR PURPOSE (WHETHER OR NOT NAESB KNOWS, HAS REASON TO KNOW, HAS BEEN ADVISED, OR IS OTHERWISE IN FACT AWARE OF ANY SUCH PURPOSE), WHETHER ALLEGED TO ARISE BY LAW, BY REASON OF CUSTOM OR USAGE IN THE TRADE, OR BY COURSE OF DEALING. EACH USER OF THIS CONTRACT ALSO AGREES THAT UNDER NO CIRCUMSTANCES WILL NAESB BE LIABLE FOR ANY DIRECT, SPECIAL, INCIDENTAL, EXEMPLARY, PUNITIVE OR CONSEQUENTIAL DAMAGES ARISING OUT OF ANY USE OF THIS CONTRACT.

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NAESB Standard 6.3.1
September 5, 2006

TRANSACTION CONFIRMATION
FOR IMMEDIATE DELIVERY

EXHIBIT A

Letterhead/Logo

Date: ________________, ______

Transaction Confirmation #: __________

This Transaction Confirmation is subject to the Base Contract between Seller and Buyer dated . The terms of this Transaction Confirmation are binding unless disputed in writing within 2 Business Days of receipt unless otherwise specified in the Base Contract.

SELLER:		BUYER:
______________________________________________		______________________________________________
______________________________________________		______________________________________________
______________________________________________		______________________________________________
Attn: _________________________________________		Attn: __________________________________________
Phone: ________________________________________		Phone: _________________________________________
Fax: __________________________________________		Fax: ___________________________________________
Base Contract No. _______________________________		Base Contract No. ________________________________
Transporter ____________________________________		Transporter. _____________________________________
Transporter Contract Number. ______________________		Transporter Contract Number. ______________________

Contract Price: $________/MMBtu or __________________________________________________________

Delivery Period: Begin: ___________, _____

End: ___________, _____

Performance Obligation and Contract Quantity: (Select One)

Firm (Fixed Quantity):	Firm (Variable Quantity):	Interruptible:
_____ MMBtus/day	_______ MMBtus/day Minimum	Up to ______ MMBtus/day
¨ EFP	_______ MMBtus/day Maximum
	subject^:to Section 4.2. at election of
	¨ Buyer or ¨ Seller

Delivery Point(s): _______________________

(If a pooling point is used, list a specific geographic and pipeline location):

Special Conditions:

Seller: _________________________________________		Buyer: _______________________________________

By: __________________________________________		By: _________________________________________

Title: _________________________________________		Title: ________________________________________

Date: _________________________________________		Date: ________________________________________

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NAESB Standard 6.3.1
September 5, 2006

SPECIAL PROVISIONS ATTACHED TO AND FORMING PART OF THE

BASE CONTRACT FOR SALE AND PURCHASE OF NATURAL GAS

Dated November 20, 2009

By and between

Regency Gas Marketing LLC

And

E & P Co., LLC

Regency Gas Marketing LLC and E & P Co., LLC hereby agree to amend the Base Contract for Sale and Purchase of Natural Gas referenced above to incorporate the modifications set forth below.

Section 1. PURPOSES AND PROCEDURES

Section 1.2 is amended by replacing the first two sentences with the following:

“The parties will use the following Transaction Confirmation procedure. Any Gas purchase and sole transaction may be effectuated in an EDI transmission or telephone conversation or a conversation using an instant messenger program (“IM Conversation”), with the offer and acceptance constituting the agreement of the parties.”

Section 1.2 is further amended by add the word “in writing;” in the last sentence after the words “both parties” and before “provided” so that the sentence reads:

“such provisions shall not be deemed to be accepted pursuant to Section 1.3 but must be expressly agreed to by both parties in writing; provided that the foregoing shall not involidate any transaction agreed to by the parties.”

Section 7 BILLING, PAYMENT, AND AUDIT

Section 7.5 is deleted in its entirety and replaced by the following:

“If the invoiced party fails to remit the full amount payable when due, a late fee shall be assessed an the unpaid portion and shall accrue from the date due until the date of payment in an amount equal to the then standard rate opplied by Regency Gas Marketing LLC.”

Section 10. FINANCIAL RESPONSIBILITY

Section 10.1 is hereby amended by (i) adding the word “or” in the second sentence, after the comma following the word “prepayment” and before “a security interest”, and is further amended by deleting the final two sentences of the paragraph so that it reads:

“If either party (“X”) hos reosonoble grounds for insecurity regarding the performance of any obligotion under this Contract (whether or not then due) by the other party (“Y”) (including, without limitation, the occurrence of a material change in the creditworthiness of Y or its

Guarantor, if applicable), X may demand Adequate Assurance of Performance. ‘Adequate Assurance of Performance’ shall mean sufficient security in the form, amount, for a term, and from an issuer, all as reasonably acceptable to X, including, but not limited to cash, a standby irrevocable letter of credit, a prepayment, or a security interest in an asset or guaranty.”

Section 10.2 (vii) is amended by removing the words “but at least one Business Day” from the sentence, and by replacing the words “48 hours” with “72 hours” :

“fail to give Adequate Assurance of Performance under Section 10.1 within 72 hours of a written request by the other party;”

Section 10.3.1 is amended by deleting the final sentence and replacing it with the following sentence:

“The discount rate used in calculating net present value shall be determined by the Non-Defaulting Party in a commercially reasonable manner.”

Section 10.4 is hereby amended by deleting the last sentence of the paragraph and replacing it with the following:

“Late fees on any unpaid portion of the Net Settlement Amount as adjusted by setaffs, shall accrue from the date due until the date of payment in an amount equal to the then standard rate applied by Regency Gas Marketing LLC”

Section 11. FORCE MAJEURE

Section 11.3 (iv) is hereby amended by deleting subsection (iv) in its entirety and replacing it with the following:

“(iv) the loss of Buyer’s market(s) or Buyer’s inability to use or resell Gas purchased hereunder, except, in either case, as a result of events that qualify as a Force Majeure as provided in Section 11.2; or”

Section 11.3 (v) is hereby amended by deleting subsection (v) in its entirety and replacing it with the following:

“(v) the loss or failure of Seller’s gas supply or depletion of reserves, except in either case, as a result of events that qualify as a Force Majeure as provided in Section 11.2.”

Section 12. TERM

Section 12 is hereby amended by replacing the number “30” with the number “60” so the sentence reads as follow:

“This Contract may be terminated on 60 Day’s written Notice, but shall remain in effect until the expiration of the latest Delivery Period of any transaction(s).”

Regency Gas Marketing LLC
By: Regency Gas Services LP, its sole member
By: Regency OLP GP LLC, its general partner

By:	/s/ Pat Giroir
Pat Giroir
Vice President
Date:	12/2/09

E & P Co., LLC

By:	/s/ Charles E. Edwards
Name: Charles E. Edwards
Title: Member/Manager
Date: November 20, 2009

By:	/s/ Osman Kaldirim, Jr.
Name: Osman Kaldirim, Jr.
Title: Member/Manager
Date: November 20, 2009

EX-10.4 7 v367661_ex10-4.htm EXHIBIT 10.4

2001 Bryan Street

Suite 3700

Dallas, TX 75201

MAIN 214.750.1771

FAX 214.750.1749

www.regencyenergy.com

September 21, 2011

Mr. Samta Gupta

E & P Company, LLC

2500 Tanglewilde St., Suite 260

Houston, TX 77063

RE:

Amendment to Base Contract for Sale and Purchase of Natural Gas Between E & P Company, LLC and Regency Field Services, LLC Effective September 1, 2011 (Regency Contract No. 7238)

Mr. Gupta:

Enclosed you will find:

Two (2) originals of the referenced Agreement(s). If the enclosed meets with your approval, please execute and return both partially executed originals to my attention at the letterhead address. I will complete the execution process and return a fully executed original to you for your files.

Two (2) partially executed originals of the referenced Agreement(s). If the enclosed meets with your approval, please provide for execution of each and return one (1) fully executed original to my attention for our files.

Please initial the changes on the enclosed Agreement(s), retain one (1) original and return one (1) original to me for our files.

One (1) fully executed original of the above referenced agreement for your files. Regency has retained an original for our files.

Regency Field Services, LLC appreciates the opportunity to do business with your company and looks forward to our continuing relationship.

If you should have any questions, please contact Jennifer Rost at (214) 840-5673.

Sincerely,

/s/ Jenny Zacarias

Jenny Zacarias

Contract Analyst

Enclosure

7238

AMENDMENT TO

BASE CONTRACT FOR SALE AND PURCHASE OF NATURAL GAS

THIS AMENDMENT TO Base Contract for Sale and Purchase of Natural Gas (“Amendment”) is entered into as of this l^st day of September, 2011 by E&P Company, LLC and Regency Field Services LLC, formerly Regency Gas Marketing LLC, (collectively referred to as “the Parties”).

WHEREAS, the Parties desire to amend that certain Base Contract for Sale and Purchase of Natural Gas dated 11/20/2009 (the “Agreement”);

NOW, THEREFORE, for and in consideration of the premises and of the mutual covenants contained herein, the Parties agree to amend the Agreement as follows:

Section 11.2 is hereby amended by deleting it entirely and replacing it with the following:

“Force Majeure shall include, but not be limited to, the following: (i) physical events such as acts of God, landslides, lightning, earthquakes, fires, storms or storm warnings, such as hurricanes, which result in evacuation of the affected area, floods, washouts, and explosions, (ii) breakage or accident or necessity of repairs to machinery or equipment or lines of pipe; (iii) weather related events affecting an entire geographic region, such as low temperatures which cause freezing or failure of wells or lines of pipe; (iv) interruption and/or curtailment of Firm transportation and/or storage by Transporters; (v) acts of others such as strikes, lockouts or other industrial disturbances, riots, Sabotage, insurrections or wars, or acts of terror; and (vi) governmental actions such as necessity for compliance with any court order, law, statute, ordinance, regulation, or policy having the effect of law promulgated by a governmental authority having jurisdiction. Seller and Buyer shall make reasonable efforts to avoid the adverse impacts of a Force Majeure and to resolve the event or occurrence once it has occurred in order to resume performance.”

The effective date of this Amendment is September 1, 2011.

The Agreement is amended to the extent noted herein. In all other respects, it is confirmed and shall continue in full force and effect.

IN WITNESS WHEREOF, the parties hereto have executed this Amendment in person or by their duly authorized officials.

Regency Field Services LLC		E&P Company, LLC ,
By: Regency Gas Services LP, its sole member
By: Regency OLP GP LLC, its general partner

BY:	/s/ Mary Ann McMichael	By:	/s/ OSMAN KALDIRIM JR.

Name:	Mary Ann McMichael	Name:	OSMAN KALDIRIM JR.
	Director, Contract Administration

Title:		Title:	VICE PRESIDENT

Date:	9/21/11	Date:	09/15/2011

EX-10.5 8 v367661_ex10-5.htm EXHIBIT 10.5

AGREEMENT setting forth the terms and conditions upon which TIBER CREEK CORPORATION ("Tiber Creek") is engaged by PRESTIGE O&G, LLC, together with any successors (collectively "Prestige") to effect transactions (the "Transactions") intended to combine E&Pco, LLC ("E&Pco") with a United States reporting company (“the Reporting Company”) and for related matters.

Services Provided.

Following its engagement, Tiber Creek and its affiliates will:

1.1. Discuss with Prestige the structure of the Transactions and actions to be taken by Prestige in preparation for the completion of the Transactions;

1.2. Transfer control of the Reporting Company to Prestige;

1.3. Prepare the agreement for the acquisition of E&Pco by the Reporting Company by merger, stock-for-stock exchange or stock-for-asset exchange as directed by Prestige ("Business Combination Agreemet");

1.4. Combine E&Pco with the Reporting Company ("the Business Combination");

1.5. Prepare and file with the Securities and Exchange Commission Forms 8-K describing the change in control of the Reporting Company and the Business Combination, as each occurs;

1.6. Following the Business Combination, prepare and file with the Securities and Exchange Commission an appropriate form of registration statement under the Securities Act of 1933 (“Registration Statement”) and all required amendments registering such securities of the Reporting Company as Prestige shall designate;

1.7. Provide for the filing by a market maker of a Form 15c-211 for the quotation or listing of E&Pco’s securities for public trading on stock exchanges for which its securities are then eligible;

1.8. Prepare any opinion letters needed for compliance with the requirements of the Financial Industry Regulatory Authority in connection with trading and with the Depository Trust Company for eligibility for the electronic transfer of shares;

1.9. Assist in establishing and maintaining relationships with market makers and broker-dealers in efforts to raise funds for E&Pco;

1.10. Take other actions appropriate to completion of the Transactions as contemplated by this agreement.

Business Combination.

2.1. Tiber Creek will provide, at its expense, the Reporting Company, which will have audited financial statements showing no material assets or liabilities, which will have registered its common stock under §12(g) of the Securities Exchange Act of 1934 ("the 1934 Act"), and which will be current in its reporting requirements under §13 of the 1934 Act.

Agreement with Tiber Creek Corporation

Page Number 2

2.2. The Reporting Company will have authorized capital of 100,000,000 shares of common stock, $.0001 par value per share, and 20,000,000 shares of preferred stock, $.0001 par value per share, of which 20,000,000 common shares have been issued and no preferred shares.

2.3. Upon the change in control of the Reporting Company there will be issued to Prestige the amount of common stock and other securities of the Reporting Company as shall be designated by Prestige. The officers and directors selected by Prestige will become the officers and directors of the Reporting Company. The name of the Reporting Company following the change in control will be chosen by Prestige.

2.4. The existing shareholders of the Reporting Company will retain 500,000 common shares of the Reporting Company (the "Shareholder Shares”). The Shareholder Shares shall be included in the Registration Statement.

2.5. The Reporting Company will not at any time take or allow any action (whether by reverse stock split or otherwise) which would have the effect of reducing the absolute number of the Shareholder Shares.

2.6. Nothing in this agreement shall prevent the Reporting Company from diluting the stock ownership of Tiber Creek by issuing additional common stock to other persons at any time.

Payments.

3.1. In full satisfaction for the services of Tiber Creek and its affiliates in regard to the Transactions described in section 1 of this agreement, Prestige will pay to Tiber Creek the amount of $100,000.

3.2. Prestige shall pay $40,000 to Tiber Creek upon the execution of this agreement and $15,000 monthly thereafter until payment in full. All payments will be deemed earned when paid or due to Tiber Creek and are non-refundable subject to the satisfactory accomplishment of the services rendered as due in Article 1 of this agreement.

Expenses.

4.1. Tiber Creek will bear its expenses incurred in regard to the Transactions, including, without limitation, travel, telephone, duplication costs, and postage.

4.2. Prestige will pay its own and third-party expenses (other than diose of Tiber Creek) including, without limitation, Federal, state and stock exchange filing fees, underwriting and market making costs, corporate financial relations, accounting fees, duplicating costs and other expenses of the Reporting Company. Tiber Creek will not incur any expenses on behalf of the Reporting Company unless permitted to do so in writing.

Agreement with Tiber Creek Corporation

Page Number 3

Affiliates.

5.1. In order to better carry out the Transactions, Tiber Creek may assign the performance of all or parts of this agreement to one or more of its affiliates or other persons, and pay such affiliates or other persons from the amounts received by Tiber Creek under this agreement. An assignment will not relieve Tiber Creek of any of its obligations under this agreement.

5.2. Prestige understands that legal services arising from this agreement will be performed by the law firm of Cassidy & Associates, which is an affiliate of Tiber Creek. Tiber Creek will pay all costs and expenses of Cassidy & Associates. Prestige understands that this agreement does not create any attorney relationship between Prestige or the Reporting Company and Cassidy & Associates.

Understandings of Prestige as a Reporting Company.

Prestige agrees that it will timely take all steps necessary to complete the Transactions to include, without limitation, causing audited financial statements to be prepared in proper form for E&Pco; obtaining consents of the Board of Directors and the shareholders of E&Pco, as required; causing all necessary documents to be properly and timely prepared, executed, approved or ratified, and filed, as appropriate; making timely and fully all required payments related to the registration and listing of the Reporting Company's securities for public trading, including filing fees; and timely taking all other actions reasonably required of it to complete the Transactions.

Performance of Services by Others.

From time to time, the achievement of certain results desired by the Reporting Company, including the promotion of interest in its public securities, may be enhanced by the services of other parties. These parties may include consultants, advertising agencies, financial analysts and similar persons who may, directly or indirectly, assist in creating interest in the Reporting Company’s securities. All compensation, costs and expenses of such parties, if engaged by the Reporting Company, will be borne by it. If not engaged by the Reporting Company such compensation, cost and expenses will be borne by the party or other entity engaging the same.

ACTIONS AND UNDERSTANDINGS FOLLOWING THE BUSINESS COMBINATION.

8.1. E&Pco understands the obligations and responsibilities that will arise in regard to its becoming a reporting company and the trading of its securities in the public market. E&Pco understands that in order to achieve the greatest market interest in its securities it, its officers and its directors, all or some, will be required to continuously interact with the financial community. This interaction will include, without limitation, timely filing of reports under the Securities Exchange Act of 1934, including audited financial statements; annual reports to shareholders and shareholder meetings; issuing periodic press releases; and meetings and discussions with existing and prospective brokers, market makers, investment bankers and institutions.

Agreement with Tiber Creek Corporation

Page Number 4

8.2. Prestige understands that the completion of the Transactions will not, in itself, result in capital investment in the Reporting Company. The public status of the Reporting Company and its introduction to market makers and others in the financial community may result in investment interest. However, investment interest will depend upon the success of the Reporting Company, market conditions and other factors over which neither Tiber Creek nor its affiliates have any control.

8.3. Prestige understands that the ultimate judgement of the financial community of the investment merits of the Reporting Company will depend upon the Reporting Company’s ability to successfully carry out its business plans and operations, to operate at a profit and similar business considerations. Prestige represents in good faith that it currently has no reason to believe that it will not be able to complete the Transactions and to achieve its business objectives.

8.4. Prestige understands that the first trading in the Reporting Company's securities may be limited, and that to increase the amount, depth and market price of its securities will require both time and effort by the Reporting Company to develop relations with market makers and to create strong and stable trading of the Reporting Company's securities.

Compliance with Securities Law.

Under the securities laws:

9.1. E&Pco and its affiliates will need to furnish all information and documents concerning it and its affiliates required for the preparation and filing of the Registration Statement by the Reporting Company which information must be complete and accurate and not contain any material misstatement or omit any material information.

9.2. The Reporting Company must at all times observe and comply with Federal and state securities laws, rules and regulations incident to the issuance and trading of its securities and must take all steps reasonably required within its control to prohibit any persons, whether or not affiliated with the Reporting Company, from engaging in any transactions in contravention of such laws, rules and regulations.

9.3. E&Pco and its affiliates must not at any time knowingly engage in any activity which would constitute a prohibited market manipulation of the securities of the Reporting Company and will need to take all steps reasonably required within its control to prohibit any officer, director, other affiliate, agent or employee from engaging in such conduct.

9.4. The Reporting Company should not issue any securities to any person for the promotion or maintenance of a trading market in the Reporting Company’s securities without first receiving an opinion of qualified counsel that such issuance will be in accord with securities laws, rules and regulations and should not, directly or indirectly, receive from such persons any capital by loan, investment or otherwise resulting from the sale or pledge of such securities.

Agreement with Tiber Creek Corporation

Page Number 5

10.

Notices.

Any notices required or permitted under this agreement shall be deemed to have been given when delivered in writing by hand, certified mail (return receipt requested) or commercial courier, such as FedEx, to the following addresses or to such other addresses as may have been given to each party in the manner provided for in this paragraph.

In the case of Prestige to

Prestige O&G, LLC

2500 Tanglewilde

Suite 260

Houston, Texas 77063

In the case of Tiber Creek to

Tiber Creek Corporation

9454 Wilshire Boulevard

Suite 612

Beverly Hills, California 90212

11.

Disputes

11.1. The parties will endeavor in good faith to resolve all disputes, controversies, or claims arising out of or relating to this agreement, or the breach thereof ("Dispute") by mediation in Houston, Texas according to the then prevailing rules and procedures of the American Arbitration Association.

11.2. In the event that such mediation does not result in the resolution of the subject Dispute within fifteen (15) days after commencement of the mediation the Dispute shall be resolved by binding arbitration in Los Angeles, California administered by the American Arbitration Association under its Commercial Arbitration Rules, and judgment on the award rendered by the arbitrator(s) may be entered in any court having jurisdiction thereof.

12.

Termination.

12.1. Tiber Creek may terminate diis agreement at its election, without further obligation or liability, at any time (i) that Tiber Creek has a reasonable basis to believe that any aspect of the Transactions would constitute a fraud or deception on the market or (ii) that Prestige fails to meet its obligations under this agreement in a manner which would constitute a material breach.

12.2. Prestige may terminate this agreement at its election, without further obligation or liability, at any time that Tiber Creek fails to meet its obligations under this agreement in a manner which would constitute a material breach.

Agreement with Tiber Creek Corporation

Page Number 6

12.3. In the case of any claim of a material breach the party claimed against shall have 5 days following notice of a claim to cure such breach unless such breach, by its nature, cannot be cured.

13.

Miscellaneous.

13.1. Covenant of Further Assurances. The parties agree to take any further actions and to execute any further documents which may from time to time be necessary or appropriate to carry out the purposes of this agreement.

13.1.(a) Scope of Agreement. This agreement constitutes the entire understanding of the parties. No undertakings, warranties or representations have been made other than as contained herein, and no party shall assert otherwise. This agreement may not be changed or amended orally.

13.1.(B) Currency. All references to currency in this agreement are to United States Dollars.

13.1 (c) Review of Agreement. Each party acknowledges that it has had time to review this agreement and. as desired, consult with counsel. In the interpretation of this agreement, no adverse presumption shall be made against any party on the basis that it has prepared, or participated in the preparation of, this agreement.

13.2. Ratification by the Reporting Company. The parties will cause the Reporting Company to ratify and accept this agreement so that it constitutes a binding obligation between the Reporting Company and Tiber Creek according to its terms.

13.3. A confidentiality agreement which is attached to this agreement has been executed by the parties and constitutes an integral part of this agreement.

14.

Effective Date.

The effective date of this agreement is March 7, 2013.

IN WITNESS WHEREOF, the parties have approved and executed this agreement.

TIBER CREEK CORPORATION


President

PRESTIGE O&G, LLC

[ILLEGIBLE]
Chairman of the Board

EXHIBIT A

CONFIDENTIALITY AGREEMENT

THIS CONFIDENTIALITY AGREEMENT (“Agreement”) is made and effective this 5th day of March, 2013, by and between Prestige O&G LLC (“Company”) and Tiber Greek Corporation, (“Recipient”) In this Agreement, Company and Recipient may, sometimes, be referred to collectively as the “Parties” and, individually, as a “Party”.

WHEREAS, Company has certain Confidential Information (hereinafter defined) concerning its business activities and properties;

WHEREAS, Recipient desires to review such Confidential Information in connection to this Agreement signed on — between the parties to conduct certain tasks and/or in order to facilitate its determination of whether to pursue further evaluation of a possible business relationship with Company, and,

WHEREAS, Company desires to provide such Confidential Information to Recipient in order that Recipient may fully review and evaluate whether to pursue further such discussions.

NOW, THEREFORE, in consideration of the premises, mutual covenants, and agreements herein contained, and other good and valuable consideration, the receipt, and sufficiency of which are hereby acknowledged, the Parties agree as follows.

Company agrees to disclose to Recipient various information, documents and other materials, some of which are proprietary to Company or may constitute trade secrets of Company, but all of which are confidential, relating to its business including technical, financial and commercial data (all of the foregoing "Confidential Information") for the sole and exclusive purpose of evaluating a possible business relationship with Company (herein “Transaction”).

Recipient agrees that any and all of the Confidential Information disclosed by Company shall be kept strictly confidential and shall not be sold, traded, published or otherwise disclosed to anyone in any manner whatsoever, including by means of photocopy or other reproduction, without the prior written consent of Company, except as provided elsewhere in this Agreement.

Recipient may disclose Confidential Information without the prior written consent of Company only to the extent such information is:

a. Already known to Recipient as of the date of disclosure hereunder and is not otherwise subject to an obligation of confidentiality;

b Already in possession of the public or becomes available to the public other than through the act or omission of Recipient;

c. Required to be disclosed under applicable law or by a governmental order, decree, regulation or rule (provided, however, that Recipient shall give written notice to Company prior to such disclosure in order to enable Company to seek avoidance of such disclosure); or

d. Acquired independently from a third party that has the legal right to disseminate such information and so represents in writing prior to the time it is acquired by Recipient.

Disclosures that are specific shall not be deemed to be within the foregoing exceptions merely because they are embraced by more general disclosures in the public domain or in Recipient’s possession.

To the extent required to evaluate the Transaction, Recipient may disclose the Confidential Information to an Affiliated Recipient (as defined below) without the prior written consent of Company, provided that Recipient guarantees the adherence of such Affiliated Recipient to the terms of this Agreement.

"Affiliated Recipient" shall mean any corporation or other legal entity which (a) controls, either directly or indirectly, Recipient, or (b) that is controlled, directly or indirectly, by Recipient, or (c) is directly or indirectly controlled by a company or entity which directly or indirectly controls Recipient. "Control" means the right to exercise more than 50% of the voting rights in the appointment of the directors of such company.

Recipient may disclose the Confidential Information without the prior written consent of Company to such of the following persons who have a clear need to know the Confidential Information in order to evaluate the Transaction:

a Employees, officers and directors of Recipient;

b Employees, officers and directors of an Affiliated Recipient, or,

c. Any professional consultant or agent retained by Recipient for the purpose of evaluating the Transaction.

Prior to making any such disclosures to persons under subparagraph (c) above, however, Recipient shall obtain an undertaking of confidentiality, in the same form and content as this Agreement, from each such person or entity.

Notwithstanding any other provision of this Agreement, Recipient shall only use or permit the use of the Confidential Information for the purpose of conducting the evaluation of the Transaction and shall restrict use and/or circulation to only those who need to know it for such purpose to the extent specifically provided herein.

Recipient shall be responsible for ensuring that all persons to whom the Confidential Information is disclosed as permitted under this Agreement shall keep such information confidential and shall not disclose or divulge the same to any unauthorized person Further, Recipient shall treat the Confidential Information with at least the same degree of care Recipient accords its own confidential information.

The Confidential Information shall remain the property of Company, and Company may demand the return thereof at any time upon giving written notice to Recipient. Within 30 days of receipt of such notice (and, in any event, upon the determination by Recipient not to proceed further with the Transaction) Recipient shall return all of the original Confidential Information in tangible or electronic form and shall destroy all copies and reproductions in its possession or under its control or in the possession or under the control of persons, if any, to whom it was disclosed pursuant to Paragraphs 4 and 5 hereof.

The obligations under this Agreement shall continue indefinitely, unless specifically agreed by the Parties in writing, which shall refer to this Section 9.

10.

Company hereby represents and warrants that it has the right and authority to disclose the Confidential Information to Recipient. Company, however, makes no representations or warranties, express or implied, as to the quality, accuracy and completeness of the Confidential Information disclosed hereunder. Company, its officers, directors, shareholders, and employees shall have no liability whatsoever with respect to the use of or reliance upon the Confidential Information by Recipient and Recipient disclaims any such reliance.

11.

Recipient agrees that the Confidential Information is unique, constitutes trade secrets, and may be proprietary to Company and any remedy at law for breach of this Agreement will be inadequate. Therefore, Company shall be entitled, in addition to any other remedies it may have, to obtain temporary or permanent injunctive relief for any breach or threatened breach of this Agreement without proof of actual damages caused to Company by such breach or threatened breach and without posting of bond either before or during any legal proceedings in connection herewith.

12.

Neither this Agreement, nor any disclosure of information hereunder, in any way:

Obligates either Party to continue or initiate any discussions concerning the Transaction or any business relationship of any kind or constitutes or confirms an offer, agreement or understanding with respect to the Transaction or any business relationship of any kind;

Grants to Recipient any right or license under any copyright, trademark, patent or other intellectual property right now or hereafter owned or licensed by Company;

Obligates Company to disclose or receive any information, perform any work, enter into any license, business arrangement or other agreement;

Limits Company from developing, producing or marketing any products or services;

Creates any agency or joint relationship; or,

Limits the right of Company to enter into or not to enter into any business relationship with any Party at any time

13.

Miscellaneous.

Governing Law. This Agreement shall be deemed to have been made and delivered in the State of Texas and shall be governed as to validity, interpretation, construction, effect and in all other respects by the internal laws of the State of Texas and controlling federal law without giving effect to the conflicts of laws provisions thereof.

Successors. Except as otherwise expressly provided herein, this Agreement and the provisions hereof shall inure to the benefit of, and be binding upon, the successors of the Parties, but may not be assigned by either Party without the express written consent of the other.

Entire Agreement. This Agreement constitutes the full and entire understanding and agreement between the Parties with regard to the subjects hereof.

Further Assurances. The Parties hereto agree to execute and deliver such other documents and take such other actions, as may be necessary or desirable to carry out the provisions of this Agreement.

Amendment or Waiver. This Agreement may be modified or amended only by a writing signed by both Parties and expressly stating that it constitutes such a modification or amendment. Only a writing signed by the Party sought to be bound by the waiver and expressly stating that it constitutes such a waiver hereof may waive a provision.

Severability. In the event any provision of this Agreement shall be invalid, illegal, or unenforceable, the validity, legality, and enforceability of the remaining provisions shall not in any way be affected or impaired thereby.

Titles and Subtitles. The titles of the paragraphs and subparagraphs of this Agreement are for convenience of reference only and are not to be considered in construing this Agreement.

Counterparts This Agreement may be executed in any number of counterparts, each of which shall be an original, but all of which together shall constitute one instrument.

IN WITNESS WHERE OF, the Parties hereto have caused this Agreement to be executed by their duly authorized representatives on the date first above written

COMPANY:		Tiber Creek Corporation:
Prestige O&G
By:	/s/ Fuad Al-Humoud	By	/s/ James M. Cassidy
Name:	Fuad Al-Humoud	Name: James M. Cassidy
Title:	Chairman	Title President

EX-10.6 9 v367661_ex10-6.htm EXHIBIT 10.6

18 July, 2013

CREDIT TERMS AND CONDITIONS

UP TO USD Four Hundred Fifty Thousand ($ 450,000) Murabaha Facility

Nature of Transaction:

This Term Sheet represents the current contractual relationship of the commodity trade transaction(s) whereby the Beneficiary purchased on a deferred basis a specified Commodity from London Metal Exchange and immediate sold it on spot to produce immediate cash to be used as working Capital for the Beneficiary.

At the conclusion the transaction the Beneficiary had available cash and at the same future debt payment representing the purchase proceeds. The difference between the purchase deferred price and the spot sale price constitute the cost of financing in the books of the Beneficiary. This transaction is referred to as Murabaha

Purpose	:	To provide working capital financing i for of Murabaha Facility of up to USD Four Hundred Fifty Thousand Only ($ 450,000) in favour of E&P Co. to fund business and operating activities.

Beneficiary	:	E&P Co. LLC.

Financier	:	Rasan Private Equity Inc.

Facility Amount	:	USD Four Hundred Fifty Thousand ($ 450,000)

Disbursement Date	:	18^th July 2013

deferred sales price	:	$ 470,091

Maturity Date	:	31^st October 2014

Profit rate	:	3.5% per annum based on the actual 365 days year

Murabaha Payments	:	One payment of the deferred sales price on 31^st October 2014

Security		Corporate Guarantee of the Beneficiary

Documentation	:	As per Murabaha Financing Facility dated 18^th July 2013

Credit Terms and Conditions US $ 450,000

Page 1 of 1

EX-10.7 10 v367661_ex10-7.htm EXHIBIT 10.7

10 May 2010

Mr. Stephen Spafford

116 Starboard Street

San Leon, TX 77539

Dear Steve:

On behalf of E&PCo, LLC I am pleased to confirm the following full-time employment offer as Operational Manager, reporting to Vice President Osman Kaldirim, Jr. While this role will be located in our Houston office, we believe a large portion of your time will be required in the field, which is located in NE Caldwell Parish, Louisiana. The following are the highlights of this offer.

Effective Date:	01 July 2010

Annual Base Salary:	$200,000 USD

Bonuses:	You will also be eligible for participation in bonus arrangements based on the boards review of your performance and the performance of the field.

Vacation:	Under the E&PCo program, you will receive 15 days.

Group Benefits:	You are eligible for Medical, Dental and Vision Insurance at no cost to you.

Steve, we look forward to our Professional association and have confidence that it will be as rewarding to the company as it will to you. We ask that in accepting this offer that you confirm that you will be full-time employee of E&PCo and will not have any other employment or maintain any other business interests without the prior approval from E&PCo. Please let me know if you have any questions.

Sincerely,

/s/ Osman Kaldirim, Jr.
Osman Kaldirim, Jr.
Vice President

Copy:	Fuad Al-Humoud
	Dr. Osman Kaldirim
	Ayedh Al-Hajeri

x Accepted ¨ Reject Offer Because of ______________________________________

Sianed By:

Stephen D. Spafford

Dated:

May 12, 2010

2500 Tanglewilde, Suite. 492 / Houston Texas, 77063

Office (713) 978-6551 Fax (713) 978-6772

EMPLOYMENT AGREEMENT

THIS EMPLOYMENT AGREEMENT (this “Agreement”), dated the 10th day of May 2010, is made and entered by and between E & P Co., LLC, a Texas Limited Liability Company (the “Company”), and Stephen D. Spafford (the “Employee”). Each of the Company and the Employee may sometimes be referred to herein as a "Party" or, together, the "Parties".

The Company and the Employee hereby agree as follows:

Employment, Positions, and Duties.

The Company agrees to employ the Employee and the Employee agrees to accept employment with the Company upon the terms and conditions set forth in this Agreement.

During the Term (as hereinafter defined), the Employee will serve in the position of Operation Manager and will report to Vice President. The Employee will perform such services as are normally delegated to such position and such other services as may be delegated to him from time to time by Vice President. The Employee further agrees to hold without additional compensation such additional positions with the Company and its Subsidiaries as may be assigned to him

During the Term, the Employee will serve as a full-time employee of the Company and, except as may otherwise be approved in advance in writing by Vice President., and except during vacation periods and reasonable periods of absence due to sickness, personal injury, or other disability, the Employee will devote substantially all of his working time and efforts, to the best of his ability, experience and talent, to the performance of services, duties and responsibilities in accordance with this Agreement.

In connection with his employment during the Term, unless otherwise agreed by the Employee, the Employee will be based at the Company’s principal offices in Houston, Texas and in the field, based on necessity of job priority, which is located in NE Caldwell Parish, Louisiana. The Employee will undertake normal business travel on behalf of the Company, the reasonable expenses of which will be paid by the Company pursuant to Section 5.

Term. Employee's employment by the Employer shall be for 12 months and may be renewed for successive yearly periods by mutual written consent. Either Party may terminate this Agreement and the employment of Employee at any time and for any, or no, reason, except to the extent of any continuing obligations of Employee pursuant hereto, with a 30 day notice.

Compensation. The Company will pay Employee an annual salary ("Salary") of two hundred thousand Dollars ($ 200,000.00), less required deductions and withholdings. Salary will be payable at the times and in the manner consistent with the Company’s general policies regarding compensation of employees.

Employee Benefits.

During the Term, the Company will provide Employee, subject to the terms and conditions of the applicable plans as they may be amended from time to time, participation in all Company-sponsored employee benefit plans, if any, in which senior employees of the Company participate, in a manner commensurate with his position and level of responsibility in the Company. As of the date of this Agreement, the Company has no such plans.

Employee will be entitled to three weeks of vacation per year.

Expenses. The Company will reimburse the Employee for all reasonable and usual travel and other business expenses that the Employee incurs in the course of the performance of his duties to the Company under this Agreement in accordance with the Company’s policies and rules relating to the reimbursement of such expenses.

Competitive Activity; Confidentiality; Nonsolicitation.

During the Term and for a period of two year after the Termination Date, the Employee will not engage in any Competitive Activity.

During the Term, the Company agrees that it will disclose to the Employee its confidential information (“Confidential Information”) to the extent necessary for the Employee to carry out his obligations to the Company. The Employee hereby covenants and agrees that he will not during the Term or thereafter disclose to any person not employed by the Company and, then, only for the purpose of carrying out his and such employee’s obligations to the Company, or use in any manner, any Confidential Information of the Company. For purposes of this Agreement, the term “Confidential Information” will include all information of any nature and in any form that is owned, leased, or licensed by the Company, or to which the Company has rights of use or otherwise, and that is not publicly available (other than by the Employee’s breach of this Section 6 or generally known to persons engaged in businesses similar or related to those of the Company).

Confidential Information will include specifically, without limiting the generality of the foregoing, the Company’ s financial matters, customers, employees, industry contracts, business plans, project development or work plans and all other information of a confidential or proprietary nature, including that which is protected by the Uniform Trade Secrets Act. For purposes of this Section 6, the term “Company” will also include any Affiliate (collectively, the “Restricted Group”).

The foregoing obligations imposed by this Section 6 will not apply (i) during the Term, in the course of the business of and for the benefit of the Company, (ii) if such Confidential Information has become, through no fault of the Employee, generally known to the public or (iii) if the Employee is required by law to make disclosure (after giving the Company notice and, to the extent possible, an opportunity to contest such requirement).

The Employee hereby covenants and agrees that during the Term and for two year thereafter the Employee will not, without the prior written consent of the Company, on behalf of the Employee or on behalf of any person, firm or company, directly or indirectly, attempt to influence, persuade or induce, or assist any other person in so persuading or inducing, any employee of the Restricted Group to give up, or to not commence, employment or a business relationship with the Restricted Group.

No later than ten days after the Termination Date, the Employee will return to the Company all property of the Company or its Affiliates then in his possession or under his control and all property made available to him in connection with his service to the Company, including, without limitation, Company credit cards, any and all records, drawings, manuals, maps, models, notes, reports, papers, and any other documents kept or made by him in connection with his employment by the Company or any Affiliate, all computer hardware and software, files, memoranda, correspondence, financial data, keys, and security access cards.

The Employee and the Company agree that the covenants contained in this Section 6 are reasonable under the circumstances, and further agree that if in the opinion of any court of competent jurisdiction any such covenant is not reasonable in any respect, such court will have the right, power, and authority to excise or modify any provision or provisions of such covenants as to the court appear not reasonable in a manner acceptable to the Parties and to enforce the remainder of the covenants as so amended.

The Employee acknowledges and agrees that the remedy at law available to the Company for breach of any of his obligations under this Section 6 would be inadequate and that damages flowing from such a breach may not readily be susceptible to being measured in monetary terms. Accordingly, the Employee acknowledges, consents, and agrees that, in addition to any other rights or remedies that the Company may have at law, in equity, or under this Agreement, upon adequate proof of his violation of any such provision of this Agreement, the Company will be entitled to immediate injunctive relief and may obtain a temporary order restraining any threatened or further breach, without the necessity of proof of actual damage.

Successors and Binding Agreement.

This Agreement will be binding upon and inure to the benefit of, and enforceable by, the Company and any successor to the Company including, without limitation, any persons acquiring directly or indirectly all or substantially all of the business or assets of the Company whether by purchase, merger, consolidation, reorganization, or otherwise (and such successor will thereafter be deemed the “Company” for the purposes of this Agreement), but will not otherwise be assignable, transferable, or delegable by the Company.

This Agreement will inure to the benefit of, and be enforceable by, the Employee and, upon the Employee’s personal or legal representatives, executors, administrators, successors, heirs, distributes, and legatees. During the Term, this Agreement will supersede the provisions of any employment or other agreement between the Employee and the Company that relates to any matter that is also the subject of this Agreement, and such provisions in such other agreements will be null and void.

This Agreement is personal in nature and neither of the parties hereto will, without the consent of the other, assign, transfer or delegate this Agreement or any rights or obligations hereunder except as expressly provided in Sections 7(a) and (b). Without limiting the generality or effect of the foregoing, the Employee’s right to receive payments hereunder will not be assignable or transferable, whether by pledge, creation of a security interest, or otherwise, other than by a transfer by the Employee’s will or by the laws of descent and distribution and, in the event of any attempted assignment or transfer contrary to this

Section 7(c), the Company will have no liability to pay any amount so attempted to be assigned or transferred.

Notices. All notices, requests, demands, claims, and other communications that are required to be, or which may be, given by either Party (“Notifying Party”) under this Agreement (each, a “Notice”) shall be in writing addressed to the other Party (“Intended Recipient”), at the relevant Intended Recipient’s address set forth below. Any Notice shall be (i) delivered in person or by same day or overnight courier, (ii) sent by electronic facsimile or E-mail transmission, or (iii) mailed, certified first class mail, postage prepaid, return receipt requested, to the Intended Recipient as follows:

If to Company:

Address:	2500 Tanglewilde St. Suite 260
	Houston, TX 77063
Telephone	(713) 978-6551
Fax:	(713) 978-6772
E-mail:	okaldirimj@e-pco.com

If to Employee:

Address:	116 Starboard St.
	San Leon, TX 77539
Tel:	(713) 447-1862
Fax:
E-mail:	sdspafford@yahoo.com

or to such other address as the Intended Recipient shall have furnished to the Notifying Party by Notice given in accordance with this Section. A Notice shall be effective (i) if delivered in person or by courier, upon actual receipt by the Intended Recipient, (ii) if sent by electronic facsimile or email transmission, when the Notifying Party receives facsimile or email confirmation that such notice was received at the facsimile number or email address, as the case may be, of the Intended Recipient, or (iii) if mailed, upon the earlier of five (5) business days after deposit in the mail or the date of delivery as shown by the return receipt therefor.

Governing Law. The validity, interpretation, construction, and performance of this Agreement will be governed by and construed in accordance with the laws of the State of Texas (without giving effect to the principles of conflict of laws thereof) and controlling federal law.

10.

Validity. If any provision of this Agreement or the application of any provision hereof to any person or circumstances is held invalid, unenforceable or otherwise illegal, the remainder of this Agreement and the application of such provision to any other person or circumstances will not be affected, and the provision so held to be invalid, unenforceable or otherwise illegal will be reformed to the extent (and only to the extent) necessary to make it enforceable, valid or legal.

If any one or more of the provisions of this Agreement are ruled or determined to be unenforceable by a competent authority having jurisdiction, in whole or in part, for any reason, the remaining provisions shall remain fully operative. In such event, the Parties shall cooperate in good faith to agree to implement such revisions therein, or amendments thereof, in such manner as shall obviate such defects and give effect to such determinations while preserving the existing benefit of its bargain for each of the Parties. Provided, further, however, that the implementation of such rulings or determinations does not adversely i) affect the economic relationship of any of the Parties or the Company; ii) deprive any of the Parties or the Company of the benefit of its bargain; or, iii) cause any of the Parties or the Company to incur additional material obligations or liabilities. Such approval or disapproval by any of the Parties or the Company shall not be withheld, delayed or conditioned unreasonably.

11.

Miscellaneous. No Provision of this Agreement may be modified, waived, or discharged unless such waiver, modification, or discharge is agreed to in writing signed by the Employee and the Company. No waiver by either Party hereto at any time of any breach by the other Party hereto or compliance with any condition or provision of this Agreement to be performed by such other Party will be deemed a waiver of similar or dissimilar provisions or conditions at the same or at any prior or subsequent time. No agreements or representations, oral or otherwise, expressed or implied with respect to the subject matter hereof have been made by either Party that are not set forth expressly in this Agreement.

12.

Survival. Notwithstanding any provision of this Agreement to the contrary, the Parties’ respective rights and obligations under this Section 12 and Section 6 will survive any termination or expiration of the Term or the termination of the Employee’s employment for any reason whatsoever.

13.

Counterparts. This Agreement may be executed in one or more counterparts, each of which will be deemed to be an original but all of which together will constitute one and the same agreement.

IN WITNESS WHEREOF, the parties have caused this Agreement to be duly executed and delivered as of the date first above written.

COMPANY:

E & PCo., LLC
By	/s/ Osman Kaldirim Jr.
	Name: Osman Kaldirim Jr.
	Title: Vice President

EMPLOYEE:

	/s/ Stephen D. Spafford
	Name: Stephen D.Spafford
	Title: Operations Manager

EX-10.8 11 v367661_ex10-8.htm EXHIBIT 10.8

EMPLOYMENT AGREEMENT

THIS AGREEMENT (this "Agreement") is made and entered into this 8^th day of June, 2009, but effective as set forth below, by and between Samta Gupta (hereinafter referred to as "Employee"), and E & Pco, LLC ("Employer"). As used herein, each of Employee and Employer may, from time to time be referred to as a “Party” and, together the “Parties”.

WHEREAS, Employer desires to employ Employee as Accountant; and,

WHEREAS, Employee desires to accept such employment on the terms and conditions herein set forth;

NOW, THEREFORE, for and in consideration of the premises and the mutual covenants herein contained and other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, Employer and Employee hereby agree as follows.

AGREEMENT

Employment

Subject to the terms and conditions of this Agreement, Employer agrees to employ Employee as Accountant, and Employee hereby accepts such employment with Employer.

Term

The term (the "Term") of this Agreement shall commence on June 8, 2009 (hereinafter referred as the "Effective Date"), and shall continue thereafter until terminated in accordance herewith ("Term").

Title and Authority

Employee agrees to act as Accountant of Employer and perform the duties of such position. Employee shall render as may be reasonably delegated to her. Employee further agrees to hold such additional positions with the Employer as may be assigned to her from time to time by the Employer. In performing such duties hereunder, Employee shall give Employer the benefit of her special knowledge, skills, contacts and business experience. During the Term, Employee will be the Company’s full-time employee and, except as may otherwise be approved in advance in writing by the Employer, and except during vacation periods and reasonable periods of absence due to sickness, personal injury, or other disability, the Employee will devote substantially all of her working time and efforts to her duties under this Agreement. Notwithstanding the foregoing, Employee may (i) manage personal and family investments and (ii) serve as an officer, director, trustee, or otherwise participate in purely educational, welfare, social, charitable, religious and civic organizations. In connection with her employment during the Term, unless otherwise agreed by Employee, the Employee will be based at the Company’s office in Houston, Texas.

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Salary

As compensation for services rendered under this Agreement, Employee shall be entitled to receive from the Employer an aggregate salary of fifty thousand Dollars ($50,000) per annum (“Salary”). The Salary will be paid in equal installments in accordance with Employer's normal payroll practice for senior executives, less the usual deductions/withholdings such as FICA, Medicare, FUTA, SUTA, and other taxes/fees, if any.

Nothing in this Agreement shall either prevent or require the Employer from increasing, in its sole and absolute discretion, prospectively or retroactively, any compensation or other benefits payable or provided to Employee.

Medical Care Plan

Employer does not have a group medical care plan, but in the event it does adopt such a plan, Employee will be provided the opportunity to participate. Until such time, if ever, Employee may procure individual medical care insurance (the premium for which shall be paid by Employer) not less favorable to Employee in terms of coverage and benefits than that which is provided in any medical insurance policy of other management employees, the premiums for which are paid by Company.

Vacation

Employee shall be entitled to two weeks paid vacation in accordance with Employer's written vacation policy, as in effect from time to time during the Term.

Termination

General

Employer and Employee shall have the right to terminate the employment of Employee as set forth in this Section 7.

Incapacity of Employee to Perform

(i) If Employee shall become ill or be injured or otherwise become incapacitated such that, in the good faith opinion of the Employer, she cannot carry out and perform fully her duties hereunder, and such incapacity shall continue for a period of ninety (90) consecutive days, the Employer may, at any time after the ninety (90) day period has passed, by giving Employee written notice, fully and finally terminate her employment under this Agreement. Termination under this Section 7-b shall be effective as of the date provided in such notice.

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(ii) In connection with the termination of Employee pursuant to this Section 7-b, Employer shall pay to Employee, in equal installments as set forth in Section 4, severance pay for the remainder of the Term of this Agreement,; provided, however, that such payments shall be reduced by the aggregate amount of any payments Employee is be entitled to receive under any long term disability insurance policy, if any, provided to Employee by Employer.

(iii) Upon such termination, Employee shall receive (1) payment for any accrued but unused vacation days (the “Vacation Payment”), (2) any Salary earned, but not yet paid, through the date of Employee’s termination (the “Salary Payment”), and (3) such payments under applicable plans or programs to which the Employee is entitled pursuant to the terms of such plans or programs.

(iv) This Section 7-b shall not limit the entitlement of Employee or her beneficiaries to any benefits then available to Employee under any stock option, restricted stock, Company loan, or other benefit plan or policy that is maintained by the Company for the Employee’s benefit. The rights of Employee described in this paragraph shall be in addition to and not to the exclusion of, the other remedies and termination rights set forth in this Agreement.

Death of Employee

Upon termination as a result of the death of the Employee, Employee's estate or, if applicable, her heirs shall receive (i) the Salary Payments, (ii) the Vacation Payment, and (iii) any death benefits under the employee benefit programs of the Company. This Section 7-b shall not limit the entitlement of the Employee’s estate or beneficiaries to any death or other benefits then available to the Employee under any life insurance, stock option, restricted stock, Company loan, or other benefit plan or policy that is maintained by the Company for the Employee’s benefit.

Termination for Cause

In addition to any other remedies that Employer may have at law or in equity, the Employer may terminate Employee's employment under this Agreement by giving Employee written notice of such termination upon the EMPLOYER’ determination that “Cause” therefore exists. “Cause” means that, prior to any termination pursuant to this Section 7-d, the Employee shall have:

(i) been convicted of a criminal violation involving fraud, embezzlement or theft in connection with her duties or in the course of her employment with the Company;

(ii) committed intentional wrongful damage to property of the Company;

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(iii) willfully and continuously failed to perform material assigned duties after written notice from the Employer of such failure and Employee fails to cure such failure within a reasonable period after receipt of such notice, or

(iv) committed a breach of this Agreement;

and any such act shall have been demonstrably and materially harmful to the Company. Nothing herein will limit the right of the Employee to contest the validity or propriety of any such determination. Upon termination for Cause, Employee shall receive (a) the Salary Payment and (b) the Vacation Payment, and the Employee will be entitled to no other compensation, except as otherwise due to her under applicable law or the terms of any applicable plan or program.

Termination without Cause

The Employer may terminate Employee's employment under this Agreement without any cause whatsoever by giving Employee thirty (30) days' written notice. If such termination is made pursuant to this Section7-e, Employer shall pay to Employee severance pay in an amount equal to the Salary that would otherwise be payable to Employee over the period commencing on the date of termination and ending one (l) month thereafter (the "Severance Period"), assuming the Salary is the amount of Employee's Salary at the time of the termination, which severance pay shall be paid to Employee during the Severance Period in equal installments as set forth in Section 4. Upon termination pursuant to this Section 7-e, Employee shall receive, in addition to the amounts expressly provided by this Section7-e, (i) the Salary Payment and (ii) the Vacation Payment. Employee will be entitled to no other compensation, except as otherwise due to her under applicable law or the terms of any applicable plan or program. For the purpose of determining the period of continuation coverage to which the Employee or any of her dependents is entitled under Section 4980B of the internal Revenue Code of 1986, as amended (or any successor provision thereto), under any group health plan maintained by the Company or its affiliates, the Employee will be deemed to have remained employed until the end of the Severance Period.

Termination by Employee

Employee may, with or without cause, terminate her employment under this Agreement by giving Employer at least thirty (30) days' prior written notice of such termination. Upon such termination, Employee shall receive (i) the Salary Payment and (ii) the Vacation Payment, and the Employee will not be entitled to any other compensation, except as otherwise due to her under applicable law or the terms of any applicable plan or program.

Expense Reimbursement

The Employer will promptly reimburse the Employee for all travel and other business expenses that the Employee incurs in the course of the performance of her duties to the Employer under this Agreement in a manner commensurate with the Employee’s position and level of responsibility with the Employer and in accordance with the Employer’s policies and rules relating to the reimbursement of such expenses.

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Covenants

Confidentiality

i. During the Term, the Employer will be disclosing to Employee certain Confidential Information (as defined in Section 9(a)(ii) to the extent necessary for Employee to carry out her obligations to the Employer. Employee hereby covenants and agrees that she will not, during the Term or thereafter, (1) disclosc to any person (except a person while employed by the Employer who has a need to know such information in connection with his or her employment by Employer), or (2) use any Confidential Information of the Employer (except in connection with, and during the Term (and thereafter) of, her employment by Employer. The foregoing obligations imposed by this Section 9-a will not apply (i) if such Confidential Information has become, through no fault of Employee, generally known to the public or in the business in which the Employer is engaged; or, (ii) if Employee is required by law to make disclosure thereof (after giving the Employer notice and an opportunity to contest such requirement).

ii. For purposes of this Section 9(a), the term “Confidential Information” includes, but is not limited to, all confidential, proprietary, or trade secret information of any nature and in any form that is owned by the Employer and that is not publicly available, other than by Employee’s breach of this Section 9(a). Further, Confidential Information will include, without limitation, information in oral, written, electronic, or any other form, some of which is proprietary to Company or may constitute trade secrets of Company, but all of which is confidential, relating to its business including but not limited to: (1) technical, financial and commercial data; and,(2) information relating to, customers, employees, industry contracts, business plans, product or product development data, marketing plans, and all other and all other information of a confidential, or proprietary, or secret nature. For purposes of this Section 9(a), the term “Employer” shall include any parent, subsidiary, or affiliate of Employer.

Non-solicitation of Customers

The Employee hereby covenants and agrees that during the Term and for one year thereafter Employee will not, without the prior written consent of the Company, on behalf of Employee or on behalf of any person, firm or company, directly or indirectly, attempt to influence, persuade, or induce, (or assist any other person in so doing), any person known by Employee to be a customer of Employer within the States of Texas, Arizona, New Mexico, Oklahoma, Louisiana, Washington, Arkansas, or any location in which the Company is then doing business, to give up, or not to commence, a business relationship with Employer.

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No Conflicting Agreements

Employee represents and warrants to the Employer that Employee is (1) not a Party to any agreement, contract, or covenant limiting the right of Employee to be employed in any capacity, at any time, or by anyone; or, (2) imposing upon Employee or her employer any duty with respect to confidential or proprietary information or with respect to the solicitation or hiring of any person.

Breach

Employee hereby recognizes and acknowledges that irreparable injury or damage shall result to the business of Employer in the event of a breach or threatened breach by Employee of any of the terms or provisions of this Section 9, and Employee therefore agrees that Employer shall be entitled to an injunction restraining Employee from engaging in any activity constituting such breach or threatened breach. Nothing contained herein shall be construed as prohibiting Employer from pursuing any other remedies available to Employer at law or in equity for such breach or threatened breach, including, but not limited to, the recovery of damages from Employee and, if Employee is an employee of the Employer, terminating the employment of Employee in accordance with the terms and provisions of this Agreement.

Survival

Notwithstanding the termination of the employment of Employee or the termination of this Agreement, the provisions of this Section 9 shall survive and be binding upon Employee unless a written agreement that specifically refers to the termination of the obligations and covenants of this Section 9 is executed by Employer.

10.

MISCELLANEOUS

Notices

Any notices to be given hereunder by either Party to the other may be effected either by personal delivery in writing or by mail, registered or certified, postage prepaid with return receipt requested. Mailed notices shall be addressed to the Parties at the following addresses:

If to Employer:

2500 Tanglewilde St. #492

Houston TX, 77063

If to Employee:

24519 Red Bluff Trail

Katy TX, 77494

Any Party may change such Party’s address by written notice in accordance with this Section. Notices delivered personally shall be deemed communicated as of actual receipt, mailed notices shall be deemed communicated as of three (3) days after proper mailing.

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Entire Agreement

This Agreement contains the entire agreement between Employee and Employer with respect to the subject matter hereof and supersedes all prior agreements and understandings, oral or written, between Employee and Company.

Law Governing Agreement

This Agreement shall be governed by and construed in accordance with the laws of the State of Texas, and all obligations shall be performable in the State of Texas.

Waiver

No term or condition of this Agreement shall be deemed to have been waived nor shall there be any estoppel to enforce any of the terms or provisions of this Agreement except by written instrument of the Party charged with such waiver or estoppel. Further, it is agreed that no waiver at any time of any of the terms or provisions of this Agreement shall be construed as a waiver of any of the other terms or provisions of this Agreement and that a waiver at any time of any of the terms or provisions of this Agreement shall not be construed as a waiver at any subsequent time of the same terms or provisions.

Amendments

No amendment or modification of this Agreement shall be deemed effective unless and until executed in writing by all of the Parties hereto.

Severability and Limitation

All agreements and covenants contained herein are severable and, in the event any of them shall be held to be invalid by any competent court, this Agreement shall be interpreted as if such invalid agreements or covenants were not contained herein. Should any court or other legally constituted authority determine that for any such agreement or covenant to be effective that it must be modified to limit its duration or scope, the Parties hereto shall consider such agreement or covenant to be amended or modified with respect to duration and scope so as to comply with the orders of any such court or other legally constituted authority or to be enforceable under the laws of the State of Texas. All other provisions of this Agreement shall remain in full force and effect as originally written.

Assignment.

Employer may assign this Agreement in its entirety to one or more of its affiliates. If Employer is consolidated with or merged into, or if all or a part of its assets are transferred to, another corporation, under circumstances such that there is a successor corporation carrying on all or a substantial part of the business of Employer, this Agreement shall automatically, without further act, be deemed to be assigned to such successor upon completion of such transaction.

EXECUTED as of the day and year first above written.

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EMPLOYER:

	E & PCO, LLC

By:
	Its:

	E & PCO, LLC

By:	/s/ Osman Kaldirim, Jr.
	Its: Osman Kaldirim, Jr.

EMPLOYEE:

/s/ Samta Gupta
Samta Gupta

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