EXHIBIT 10.119

AMENDED AND RESTATED

SAN JUAN PROJECT PARTICIPATION AGREEMENT

AMONG

PUBLIC SERVICE COMPANY OF NEW MEXICO

TUCSON ELECTRIC POWER COMPANY

THE CITY OF FARMINGTON, NEW MEXICO

M-S-R PUBLIC POWER AGENCY

THE INCORPORATED COUNTY OF LOS ALAMOS, NEW MEXICO

SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY

CITY OF ANAHEIM

UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

March 23, 2006

TABLE OF CONTENTS

SECTION	I. PARTIES AND INTRODUCTORY MATTERS	PAGE
1	PARTIES	1
2	RECITALS	2
3	AGREEMENT	8
4	EFFECTIVE DATE AND TERMINATION	9
5	DEFINITIONS	11
	II. OWNERSHIP OF SAN JUAN PROJECT
6	OWNERSHIPS AND TITLES	21
7	CAPITAL IMPROVEMENTS AND RETIREMENTS OF SAN JUAN PROJECT AND PARTICIPANTS’ SOLELY OWNED FACILITIES	25
8	WAIVER OF RIGHT TO PARTITION	29
9	BINDING COVENANTS	30
10	MORTGAGE AND TRANSFER OF PARTICIPANTS’ INTERESTS	32
11	RIGHTS OF FIRST REFUSAL	35
12	RIGHTS OF PNM AND TEP IN WATER AND COAL	40
13	SEVERANCE OF IMPROVEMENTS	41
	III. ENTITLEMENTS TO OUTPUT OF SAN JUAN PROJECT
14	ENTITLEMENT TO CAPACITY AND ENERGY	42
15	CAPACITY ALLOCATION OF SWITCHYARD FACILITIES	44
16	USE OF FACILITIES DURING CURTAILMENTS	46

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17	START-UP AND AUXILIARY POWER AND ENERGY REQUIREMENTS	48
	IV. ADMINISTRATION
18	COORDINATION COMMITTEE	49
19	ENGINEERING AND OPERATING COMMITTEE	54
20	FUELS COMMITTEE	59
21	AUDITING COMMITTEE	66
	V. BUDGETS AND OPERATING EXPENSES
22	OPERATION AND MAINTENANCE EXPENSES	70
23	FUEL COSTS	78
24	ANNUAL BUDGETS	89
25	PAYMENT OF TAXES	90
26	MATERIALS AND SUPPLIES	91
27	EMERGENCY SPARE PARTS	93
	VI. OPERATING AGENT
28	OPERATION AND MAINTENANCE	94
29	OPERATING EMERGENCY	100
30	PAYMENT OF EXPENSES BY PARTICIPANTS	102
31	OPERATING INSURANCE	105
32	SURPLUS OR RETIRED PROPERTY	109
33	REMOVAL OF OPERATING AGENT	110
34	DEFAULTS BY OPERATING AGENT	112

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	VII. DEFAULTS, LIABILITY AND ARBITRATION
35	DEFAULTS	114
36	LIABILITY	120
37	ARBITRATION	125
	VIII. RETIREMENT AND RECONSTRUCTION
38	DESTRUCTION, DAMAGE OR CONDEMNATION OF A UNIT	128
39	RIGHTS OF PARTICIPANTS UPON TERMINATION	130
40	DECOMMISSIONING OF THE PROJECT	131
	IX. MISCELLANEOUS PROVISIONS
41	RELATIONSHIP OF PARTICIPANTS	132
42	NOTICES	133
43	OTHER PROVISIONS	137
44	EXECUTION IN COUNTERPARTS	138
45	AMENDMENTS	139

EXHIBIT I	Real Property
EXHIBIT II	Annual Minimum Coal
EXHIBIT III	Switchyard Facilities
EXHIBIT IV	Ownership of Equipment
EXHIBIT V	O&M of Equipment
EXHIBIT VI	A&G Expenses
EXHIBIT VII	Coal Allocation and Billing
EXHIBIT VIII	Adjustment of Voting Requirements
EXHIBIT IX	Fixed Fuel Expense
EXHIBIT X	Variable Fuel Expense

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PART I

PARTIES AND INTRODUCTORY MATTERS

1.0PARTIES:

The parties to this Amended and Restated San Juan Project Participation Agreement (“Agreement”) are: PUBLIC SERVICE COMPANY OF NEW MEXICO, a New Mexico corporation (“PNM”); TUCSON ELECTRIC POWER COMPANY, an Arizona corporation (“TEP”); THE CITY OF FARMINGTON, NEW MEXICO, an incorporated municipality and a body politic and corporate, existing as a political subdivision under the constitution and laws of the State of New Mexico (“Farmington”); M-S-R PUBLIC POWER AGENCY, a joint exercise of powers agency organized under the laws of the State of California (“M-S-R”); THE INCORPORATED COUNTY OF LOS ALAMOS, NEW MEXICO, a body politic and corporate, existing as a political subdivision under the constitution and laws of the State of New Mexico (“LAC”); SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY, a joint exercise of powers agency organized under the laws of the State of California (“SCPPA”); THE CITY OF ANAHEIM, a municipal corporation organized under the laws of the State of California (“Anaheim”); UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS, a political subdivision of the State of Utah (“UAMPS”); and TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC., a Colorado cooperative corporation (“Tri-State”). These parties are the participants in the San Juan Project, and are hereinafter sometimes referred to individually as a “Participant” and collectively as “Participants.”

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2.0RECITALS: This Agreement is made with reference to the following facts, among others:

2.1PNM is an electric utility engaged in the generation, transmission and distribution of electric power and energy in a part of the State of New Mexico.

2.2TEP is an electric utility engaged in the generation, transmission and distribution of electric power and energy in a part of the State of Arizona.

2.3Farmington operates a municipal electric utility engaged in the generation, transmission and distribution of electric power and energy in a part of the State of New Mexico.

2.4M-S-R is a public entity engaged in the generation, transmission, purchase and sale of electric power and energy in the western United States for the benefit of its member public agencies.

2.5LAC operates a municipal electric utility engaged in the generation, transmission and distribution of electric power and energy in a part of the State of New Mexico.

2.6SCPPA is a public entity created to acquire, construct, finance, operate and maintain generation and transmission projects on behalf of its members.

2.7Anaheim operates a municipal utility in the State of California engaged in the generation, transmission and distribution of electric power.

2.8UAMPS is a public entity created to plan, finance, develop, acquire, construct, improve, better, operate and maintain projects, or ownership interests or capacity rights therein, for the generation, transmission and distribution of electric energy for the benefit of its members.

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2.9Tri-State is a cooperative corporation created pursuant to the laws of the State of Colorado. Tri-State’s primary functions involve the generation, transmission, transformation and sale of electricity to its member distribution cooperatives.

2.10PNM and TEP each has an undivided one-half (1/2) ownership interest in the real property associated with the San Juan Project, which real property is described in Exhibit I, attached hereto and incorporated herein, and is identified therein as Parcels A through F.

2.11PNM and TEP entered into the Coal Sales Agreement with San Juan Coal Company (“SJCC”), pursuant to which SJCC agreed to supply the San Juan Project with coal. PNM and TEP also entered into the Transportation Agreement with San Juan Transportation Company (“SJTC”) dated April 30, 1984, under which coal was transported from the La Plata Mine. Subsequently, PNM and TEP entered into the Underground Coal Sales Agreement with SJCC, pursuant to which SJCC agreed to supply coal to the San Juan Project beginning January 1, 2003. The Underground Coal Sales Agreement superseded and replaced the Coal Sales Agreement, except for certain provisions of the Coal Sales Agreement which survived through the provisions of the Coal Sales Agreement Buy Out Agreement. The Transportation Agreement was terminated effective December 31, 2002, except for certain provisions which survived through provisions of the Transportation Agreement Buy Out Agreement.

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2.12PNM contracted with the United States Department of the Interior, Bureau of Reclamation, under the Colorado River Storage Project Act to purchase 20,200 acre feet of water per year from Navajo Reservoir under Contract 14-06-400-4821 dated April 11, 1968. Said contract was amended by an amendatory contract dated September 29, 1977, wherein the United States Department of the Interior, Bureau of Reclamation (i) acknowledged PNM’s assignment to TEP of an undivided one-half (1/2) interest in PNM’s rights and obligations imposed under the April 11, 1968, contract; and (ii) revised the amount of water available for consumptive use by the San Juan Project from the Navajo Reservoir from 20,200 acre feet per year to 16,200 acre feet per year. Upon expiration of the above-referenced contract with the United States Department of the Interior, Bureau of Reclamation, on December 31, 2005, water from the Navajo Reservoir is delivered to the San Juan Project under contractual arrangements with the Jicarilla Apache Nation. From time-to-time, contracts for surplus water supply may also be entered into by the Operating Agent for supply to the San Juan Project. Additional water for use at the San Juan Project is based on a Grant of Authority for 8,000 acre-feet of water, dated August 18, 1980, from Utah International (predecessor in interest to SJCC) to PNM and TEP.

2.13 The San Juan Project Co-Tenancy Agreement was executed as of February 15, 1972, effective as of July 1, 1969. The original Co-Tenancy Agreement was modified by joint action of PNM and TEP, as follows: Modification No. 1 on May 16, 1979, Modification No. 2 on December 31, 1983, Modification No. 3 on July 17, 1984, Modification No. 4 on October 25, 1984, Modification No. 5 on July 1, 1985, Modification No. 6 on April 1, 1993, Modification No. 7 on April 1, 1993, Modification No. 8 on September 15, 1993, Modification No. 9 on January 12, 1994 and Modification No. 10 on November 30, 1995 (the original of such Co-Tenancy Agreement, as amended by Modifications 1 through 10, is referred to herein as the “Co-Tenancy Agreement”).

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2.14The San Juan Project Operating Agreement was executed as of December 21, 1973, effective as of July 1, 1969. The original Operating Agreement was modified by joint action of PNM and TEP, as follows: Modification No. 1 on May 16, 1979, Modification No. 2 on December 31, 1983, Modification No. 3, on July 17, 1984, Modification No. 4 on October 25, 1984, Modification No. 5 on July 1, 1985, Modification No. 6 on April 1, 1993, Modification No. 7 on April 1, 1993, Modification No. 8 on September 15, 1993, Modification No. 9 on January 12, 1994 and Modification No. 10 on November 30, 1995 (the original of such Operating Agreement, as amended by Modifications 1 through 10, is referred to herein as the “Operating Agreement”).

2.15A San Juan Project Construction Agreement was executed as of December 21, 1973, effective as of July 1, 1969, to govern the construction of the San Juan Project; this agreement was thereafter modified from time to time and was terminated in 1995 by action of PNM and TEP.

2.16On May 16, 1979, TEP and PNM entered into an agreement whereby on that date TEP conveyed to PNM TEP’s 50 percent undivided ownership interest in Unit 4.

2.17On November 17, 1981, PNM transferred an 8.475 percent undivided ownership interest in Unit 4 to Farmington.

2.18On December 31, 1983, PNM transferred a 28.8 percent undivided ownership interest in Unit 4 to M-S-R.

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2.19On October 31, 1984, TEP transferred its 50 percent undivided ownership interest in Unit 3 to Alamito Company, which later changed its name to Century Power Company (“Century”).

2.20On July 1, 1985, PNM transferred a 7.2 percent undivided ownership interest in Unit 4 to LAC.

2.21On July 1, 1993, Century transferred a 41.8 percent undivided ownership interest in Unit 3 to SCPPA.

2.22On August 12, 1993, PNM transferred a 10.04 percent undivided ownership interest in Unit 4 to Anaheim.

2.23On June 2, 1994, PNM transferred a 7.028 percent undivided ownership interest in Unit 4 to UAMPS.

2.24On January 2, 1996, Century transferred an 8.2 percent undivided ownership interest in Unit 3 to Tri-State.

2.25 Farmington, M-S-R, LAC, SCPPA, Anaheim, UAMPS and Tri-State were classified as “Unit Participants” in the San Juan Project, pursuant to the Co-Tenancy Agreement.

2.26As of April 29, 1994, PNM, TEP, Century, SCPPA, Farmington, M-S-R, LAC and Anaheim executed the San Juan Project Designated Representative Agreement (the “DR Agreement”) to implement the requirements of the federal Clean Air Act Amendments of 1990; the DR Agreement was thereafter accepted by UAMPS and Tri-State at the time of their respective purchases of ownership interests in the San Juan Project.

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2.27As of October 27, 1999, the Participants entered into the San Juan Project Participation Agreement (“Original San Juan PPA”). The purpose of the Original San Juan PPA was to amend and restate, and to replace in their entirety, the Co-Tenancy Agreement and the Operating Agreement and to set out in one instrument all of the matters previously included in the Co-Tenancy Agreement and the Operating Agreement.

2.28The Participants desire, in this Agreement, to amend and restate the Original San Juan PPA to reflect certain amendments agreed to by the Participants including, but not limited to, changes to the provisions of the Original San Juan PPA pertaining to fuel supply.

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3.0AGREEMENT: The Participants, for and in consideration of the mutual covenants to be by them kept and performed, agree as follows.

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4.0EFFECTIVE DATE AND TERMINATION:

4.1Except as otherwise provided in Section 4.3, this Agreement shall become effective upon the later of the following dates: (a) the date upon which the FERC accepts for filing this Agreement; provided that, if the FERC orders a hearing to determine whether this Agreement is just and reasonable, this Agreement shall not become effective until the date when an order, no longer subject to judicial review, has been issued by the FERC determining this Agreement to be just and reasonable without changes or modifications unacceptable to the Participants; or (b) the date upon which the Rural Utilities Service (“RUS”) approves this Agreement on behalf of Tri-State or is deemed to have approved this Agreement on behalf of Tri-State by virtue of its failure to object to this Agreement within the time prescribed in the Tri-State loan contract with RUS, if such approval is required.

4.2Following execution by all Participants, PNM shall file a copy of this Agreement with the FERC in a timely manner. In such filing, PNM shall request waiver of applicable FERC notice requirements in order to allow this Agreement to become effective as of the earliest feasible date. All other Participants shall support PNM’s filing by the prompt filing of a certificate or letter of concurrence or intervention in support of the filing.

4.3Following (a) an order by the FERC or any other regulatory agency having jurisdiction, or (b) a letter or other communication from the RUS, if any, the Participants shall each review such order, letter or communication to determine if the FERC, RUS or any agency having jurisdiction has changed or modified a condition or conditions, deleted a condition or conditions, or imposed a new condition or conditions with regard to this Agreement; or has conditioned its approval of this Agreement upon changes or

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                modifications to a condition or conditions, deletion of a condition or conditions or imposition of a new condition or conditions. The Participant receiving such order, letter or communication shall promptly provide a copy of such order, letter or communication to the other Participants. Within fifteen (15) business days after receipt by the other Participants of the copy of the order, letter or communication, the Participants shall indicate to each other in writing their acceptance or rejection of this Agreement based upon any changes, modifications, deletions or new conditions required by the FERC, RUS or any agency having jurisdiction. A failure to notify within said fifteen (15) day period shall be the equivalent to a notification of acceptance. If any Participant rejects this Agreement because the FERC, RUS or any agency having jurisdiction has modified a condition, deleted a condition or imposed a new condition in this Agreement, or has conditioned its approval on such a change, modification, deletion or new condition, the Participants will be deemed to have rejected this Agreement and they shall attempt, in good faith, to renegotiate the terms and conditions of this Agreement to resolve such changed, modified, deleted or new condition to the satisfaction of the Participants within one hundred twenty (120) days after the date of such order, letter or communication and thereafter to obtain requisite regulatory approval of such renegotiated agreement.

4.4This Agreement shall continue in force and effect until July 1, 2022, unless otherwise agreed in writing by the Participants.

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5.0DEFINITIONS: The following terms, when used herein with initial capitalization, and whether in the singular or the plural, shall have the meaning specified:

5.1ACCOUNTING PRACTICE: Generally accepted accounting principles in accordance with FERC Accounts applicable to electric utility operations.

5.2AGREEMENT: This Amended and Restated San Juan Project Participation Agreement, including all exhibits and attachments hereto, and as may be modified or amended from time to time.

5.3AUDITING COMMITTEE: A committee which is described in Section 21.

5.4AVAILABLE OPERATING CAPACITY: The maximum net electrical capacity of each installed and operating Unit which is available at any given time to the Participants at the 345 kV buses.

5.5CAPACITY: Electrical rating expressed in megawatts (“MW”).

5.6CAPITAL IMPROVEMENTS: Any property, land or land rights added to the San Juan Project or the substitution, replacement, enlargement or improvement of any Units of Property, structures, facilities, equipment, property, land or land rights constituting a part of the San Juan Project, which in accordance with Accounting Practice would be capitalized, and also including the costs of removal, salvage or disposal of any Units of Property being replaced or substituted.

5.7COAL SALES AGREEMENT: Agreement between PNM, TEP and SJCC executed on August 18, 1980, as amended or modified from time to time and which was replaced by the Underground Coal Sales Agreement. However, certain provisions of the Coal Sales Agreement survive through the provisions of the Coal Sales Agreement Buy Out Agreement dated August 31, 2001.

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5.8COAL SALES AGREEMENT BUY OUT AGREEMENT: Agreement between PNM, TEP and SJCC executed on August 31, 2001, as may be amended or modified from time to time.

5.9COMMON PARTICPATION SHARE: Each Participant’s percentage ownership interest as set forth in Section 6.2.6.

5.10CONTROL AREA: An area comprised of an electric system or systems bounded by interconnection metering and telemetry, capable of controlling generation to maintain its interchange schedules with other control areas while maintaining frequency regulation of the interconnection.

5.11COORDINATION COMMITTEE: A committee which is described in Section 18.

5.12CO-TENANCY AGREEMENT: The agreement described in Section 2.13.

5.13DR AGREEMENT: The agreement described in Section 2.26, as amended from time to time.

5.14EMERGENCY COAL STORAGE PILE: The coal storage pile for the San Juan Project, sometimes referred to as the “minimum coal storage pile,” or as the “force majeure pile,” which is to be drawn upon when fuel deliveries are interrupted.

5.15EMERGENCY SPARE PARTS: Spare parts or auxiliary equipment, the cost of which is capitalized, which are stocked for emergency use for the San Juan Project and which are not scheduled for periodic replacement.

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5.16ENERGY: The accumulated amount of power produced over a stated time interval, expressed in kilowatt hours (“kWh”) or megawatt hours (“MWh”).

5.17ENGINEERING AND OPERATING COMMITTEE: A committee which is described in Section 19.

5.18FC LINE:That 345 kV transmission line between the San Juan generating station and the Four Corners generating plant.

5.19FIXED FUEL EXPENSE: Those expenses itemized on Exhibit IX, attached hereto and incorporated herein.

5.20FERC:The Federal Energy Regulatory Commission or any successor thereto.

5.21FERC ACCOUNTS: The FERC Uniform System of Accounts prescribed for Public Utilities and Licensees (Class A and Class B). References in this Agreement to a specific FERC account number shall mean the number in effect as of the date of this Agreement and any successor account number.

5.22FUELS COMMITTEE: A committee which is described in Section 20.

5.23MATERIALS AND SUPPLIES: Those materials and supplies, the cost of which is charged to FERC Account 154, which are stocked for use in the operation and maintenance of the San Juan Project.

5.24MINIMUM ANNUAL TONS: The quantities of coal, also defined as Minimum Annual Tons (“MAT”) in Section 8.2(F)7 of the Underground Coal Sales Agreement, and set forth in Exhibit H to the Underground Coal Sales Agreement, which amounts are shown on Exhibit II, attached hereto and incorporated herein.

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5.25MINIMUM NET GENERATION: The lowest net load at which each Unit can be reliably maintained in service on a continuous basis on coal fuel.

5.26MONTHLY MINIMUM TONS : Monthly Minimum Tons (“MMT”) as also defined in Section 8.2(F)8 of the Underground Coal Sales Agreement, shall be allocated each year to each Participant pursuant to a monthly schedule approved annually by the Fuels Committee as provided in Section 20.3.3, such that the annual sum of each Participant’s Monthly Minimum Tons equals its Common Participation Share of MAT as defined in Section 8.2(F)7 of the Underground Coal Sales Agreement. In the event that a monthly allocation of MMT has not been approved by the Fuels Committee, MMT shall be allocated to each Participant based on Common Participation Share.

5.27NET EFFECTIVE GENERATING CAPACITY: The maximum continuous ability of each Unit to produce power, less auxiliary power requirements.

5.28NET ENERGY GENERATION: The Energy generated by each Unit which is available to the respective Participants at the 345 kV bus.

5.29OPERATING ACCOUNT:The bank account(s) in the names of the Participants established by the Operating Agent pursuant to Section 28.

5.30OPERATING AGENT: The Participant or other entity which has been selected by the Participants as the entity responsible for the operation and maintenance of the San Juan Project pursuant to this Agreement.

5.31OPERATING AGREEMENT: The agreement described in Section 2.14.

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5.32OPERATING EMERGENCY: An unplanned event or circumstance at the San Juan Project which reduces or may reduce the availability of Capacity or Energy from a Unit.

5.33OPERATING FUNDS: Monies advanced to, and disbursed by, the Operating Agent on behalf of the Participants in accordance with this Agreement.

5.34OPERATING INSURANCE: Policies of insurance secured or to be secured and maintained in accordance with Section 31.

5.35OPERATING WORK: Engineering, contract preparation and administration, purchasing, repair, supervision, training, expediting, inspection, testing, protection, operation, use, management, replacement, retirement, reconstruction and maintenance of and for the benefit of the San Juan Project pursuant to this Agreement, including the administration of this Agreement and of any other Project Agreements, environmental compliance activities and the procurement of fuel and water and other necessary materials and supplies.

5.36ORIGINAL SAN JUAN PPA: The San Juan Project Participation Agreement dated October 27, 1999.

5.37PARTICIPANT: PNM, TEP, Farmington, M-S-R, LAC, SCPPA, Anaheim, UAMPS or Tri-State.

5.38PARTICIPANT COAL CONSUMPTION:Each Participant’s total San Juan Project coal consumption in tons as determined by the Operating Agent. In principle, a Participant’s Coal Consumption is comprised of its share of coal consumed in its Unit(s) plus its share of coal consumed for common loads, auxiliary loads and start-up for all Units.

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5.39PARTICIPATION SHARE: Each Participant’s percentage ownership interest in the various elements of the San Juan Project as set forth in Section 6.

5.40PROJECT AGREEMENTS: This Agreement and such other agreements as are determined by the Coordination Committee to be necessary to define the rights and duties of the Participants with respect to the San Juan Project.

5.41PROJECT COAL INVENTORY:The sum of coal in the Emergency Coal Storage Pile, silos, conveying systems, hoppers, and all other coal stored at the San Juan Project as accounted in FERC Account No. 151.

5.42PRUDENT UTILITY PRACTICE: Any of the practices, methods and acts engaged in or approved by a significant portion of the electric utility industry during the relevant time period, or any of the practices, methods and acts which, in the exercise of reasonable judgment in the light of the facts known at the time the decision was made, could have been expected to accomplish the desired result at a reasonable cost consistent with good business practices, reliability, safety and expedition. Prudent Utility Practice is intended to be acceptable practices, methods or acts generally accepted in the industry, as such practices may be affected by special operational design characteristics of the San Juan Project, the quality and quantity of fuel delivered in accordance with the Underground Coal Sales Agreement or successor agreement, the rights and obligations of the Participants in accordance with this Agreement and any other special circumstances affecting the Operating Work.

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5.43SAN JUAN PROJECT: The four unit, coal-fired electric generation plant located in San Juan County, New Mexico, near Farmington, New Mexico. The San Juan Project includes all facilities, structures, transmission and distribution lines incident to the four-unit electric generating plant. The San Juan Project does not include distribution lines, transmission lines, equipment in the Switchyard Facilities or other facilities owned exclusively by a Participant.

5.44SWITCHYARD FACILITIES: The switchyard facilities required for the San Juan Project as shown by materials listed in Exhibit III, attached hereto and incorporated herein.

5.45TOTAL MONTHLY COAL COST: The amount charged the Operating Agent each month in accordance with the Underground Coal Sales Agreement, the Coal Sales Agreement Buy Out Agreement and the Transportation Agreement Buy Out Agreement.

5.46TRANSPORTATION AGREEMENT BUY OUT AGREEMENT: Agreement between PNM, TEP and San Juan Transportation Company (“SJTC”) executed on August 31, 2001, as may be amended or modified from time to time, terminated the Transportation Agreement with SJTC dated April 30, 1984.

5.47UNDERGROUND COAL SALES AGREEMENT: Agreement between PNM, TEP and SJCC executed on August 31, 2001, as amended or modified and as may be amended or modified from time to time.

5.48UNIT: Unit 1, Unit 2, Unit 3 or Unit 4.

5.49UNIT 1: The second operating unit of the San Juan Project, which was placed in commercial service on December 31, 1976 and which presently has a net capacity rating of 327 MW.

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5.50UNIT 2: The first operating unit of the San Juan Project, which was placed in commercial service on November 30, 1973 and which presently has a net capacity rating of 316 MW.

5.51UNIT 3: The third operating unit of the San Juan Project, which was placed in commercial service on December 31, 1979 and which presently has a net capacity rating of 497 MW.

5.52UNIT 4: The fourth operating unit of the San Juan Project, which was placed in commercial service on April 27, 1982 and which presently has a net capacity rating of 507 MW.

5.53UNITS OF PROPERTY: Property as described in the FERC’s list of units of property for use in connection with the Uniform System of Accounts Prescribed for Public Utilities and Licensees Subject to the Provisions of the Federal Power Act, contained in 18 CFR Part 116, in effect on the effective date of this Agreement, as thereafter modified or amended.

5.54UTILITY PAYMENT STREAM (“UPS”): Those payments defined in Section 8.5(C) of the Underground Coal Sales Agreement

5.55VARIABLE FUEL EXPENSE: Those expenses itemized on Exhibit X, attached hereto and incorporated herein.

5.56WATER CONTRACT(S): The applicable contract or contracts under which water is delivered to the San Juan Project, as more fully described in Section 2.12.

5.57WILLFUL ACTION:

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5.57.1Action taken or not taken by a Participant (or the Operating Agent), at the direction of its directors, members of its governing body, officers or employees having management or administrative responsibility affecting its performance under a Project Agreement, which action is knowingly or intentionally taken or not taken with conscious indifference to the consequences thereof or with intent that injury or damage would probably result therefrom; or

5.57.2Action taken or not taken by a Participant (or the Operating Agent) at the direction of its directors, members of its governing body, officers or employees having management or administrative responsibility affecting its performance under a Project Agreement, which action has been determined by final arbitration award or final judgment or judicial decree to be a material default under a Project Agreement and which action occurs or continues beyond the time specified in such arbitration award or judgment or judicial decree for curing such default, or if no time to cure is specified therein, occurs or continues beyond a reasonable time to cure such default; or

5.57.3Action taken or not taken by a Participant (or the Operating Agent), at the direction of its directors, members of its governing body, officers or employees having management or administrative responsibility affecting its performance under a Project Agreement, which action is knowingly or intentionally taken or not taken with the knowledge that such action taken or not taken is a material default under a Project Agreement.

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5.57.4The phrase “employees having management or administrative responsibility,” as used in this Section 5.57, means employees of a Participant who are responsible for one or more of the executive functions of planning, organizing, coordinating, directing, controlling and supervising such Participant’s performance under a Project Agreement; provided however, that, with respect to employees of the Operating Agent acting in its capacity as such and not in its capacity as a Participant, such phrase shall refer only to (i) the senior employee of the Operating Agent on duty at the San Juan Project who is responsible for the operation of the Units, and (ii) anyone in the organizational structure of the Operating Agent between such senior employee and an officer.

5.57.5Willful Action does not include any act or failure to act which is merely involuntary, accidental or negligent.

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PART II

OWNERSHIP OF SAN JUAN PROJECT

6.0OWNERSHIPS AND TITLES:

6.1PNM and TEP, respectively, each has an undivided one-half (1/2) ownership interest in the real property interests described in Exhibit I as Parcels A through F.

6.2Unless otherwise provided in Exhibit IV, the Units and other facilities of the San Juan Project and Capital Improvements shall be owned and title held by the Participants, in the following percentages:

6.2.1For Units 1 and 2 and for all equipment and facilities directly related to Units 1 and 2 only, in accordance with the following percentages:

6.2.1.1PNM: 50 percent

6.2.1.2TEP: 50 percent

6.2.1.3M-S-R: 0 percent

6.2.1.4Farmington: 0 percent

6.2.1.5Tri-State: 0 percent

6.2.1.6LAC: 0 percent

6.2.1.7SCPPA: 0 percent

6.2.1.8Anaheim: 0 percent

6.2.1.9UAMPS: 0 percent

6.2.2For Unit 3 and for all equipment and facilities directly related to Unit 3 only, in accordance with the following percentages:

6.2.2.1PNM: 50 percent

6.2.2.2TEP: 0 percent

6.2.2.3M-S-R: 0 percent

6.2.2.4Farmington: 0 percent

6.2.2.5Tri-State: 8.2 percent

6.2.2.6LAC: 0 percent

6.2.2.7SCPPA: 41.8 percent

6.2.2.8Anaheim: 0 percent

6.2.2.9UAMPS: 0 percent

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6.2.3For Unit 4 and for all equipment and facilities directly related to Unit 4 only, in accordance with the following percentages:

6.2.3.1PNM: 38.457 percent

6.2.3.2TEP: 0 percent

6.2.3.3M-S-R: 28.8 percent

6.2.3.4Farmington: 8.475 percent

6.2.3.5Tri-State: 0 percent

6.2.3.6LAC: 7.20 percent

6.2.3.7SCPPA: 0 percent

6.2.3.8Anaheim: 10.04 percent

6.2.3.9UAMPS: 7.028 percent

6.2.4For equipment and facilities common to Units 1 and 2 only, in accordance with the following percentages:

6.2.4.1PNM: 50 percent

6.2.4.2TEP: 50 percent

6.2.4.3M-S-R: 0 percent

6.2.4.4Farmington: 0 percent

6.2.4.5Tri-State: 0 percent

6.2.4.6LAC: 0 percent

6.2.4.7SCPPA: 0 percent

6.2.4.8Anaheim: 0 percent

6.2.4.9UAMPS: 0 percent

6.2.5For equipment and facilities common to Units 3 and 4 only, in accordance with the following percentages:

6.2.5.1PNM: 44.119 percent

6.2.5.2TEP: 0 percent

6.2.5.3M-S-R: 14.4 percent

6.2.5.4Farmington: 4.249 percent

6.2.5.5Tri-State: 4.1 percent

6.2.5.6LAC: 3.612 percent

6.2.5.7SCPPA: 20.9 percent

6.2.5.8Anaheim: 5.07 percent

6.2.5.9UAMPS: 3.55 percent

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6.2.6For equipment and facilities common to all of the Units in accordance with the following percentages:

6.2.6.1PNM: 46.297 percent

6.2.6.2TEP: 19.8 percent

6.2.6.3M-S-R: 8.7 percent

6.2.6.4Farmington: 2.559 percent

6.2.6.5Tri-State: 2.49 percent

6.2.6.6LAC: 2.175 percent

6.2.6.7SCPPA: 12.71 percent

6.2.6.8Anaheim: 3.10 percent

6.2.6.9UAMPS: 2.169 percent

6.2.7San Juan Project equipment and facilities not included in Sections 6.2.1 through 6.2.6 which were in service as of May 16, 1979, remain in individual one-half (1/2) ownership, with each of PNM and TEP retaining title to an equal undivided one-half (1/2) interest therein; provided, however, that subsequent to the in-service date of Unit 4, PNM, on behalf of itself and the Participants to which PNM conveyed ownership interests and generation entitlements in the San Juan Project, shall have the right to use sixty-five percent (65%), and TEP, on behalf of itself and the Participants which succeeded to TEP-conveyed ownership interests and generation entitlements in the San Juan Project, shall have the right to use thirty-five percent (35%) of the real property associated with the San Juan Project, the water, the coal inventory, the then existing oil for ignition and flame stabilization, and the use of the 345 kV switchyard capacity up to the combined installed capacity of Units 1, 2, 3 and 4, except as otherwise provided in Section 7, and except that, subject to Section 15.2.3, PNM and TEP shall each be entitled to use 50 percent (50%) of switchyard capacity in excess of the combined installed capacity of Units 1, 2, 3 and 4 for the San Juan Project.

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6.2.8Exhibit IV (a through h), attached hereto and incorporated herein, is a partial list of equipment and facilities of the San Juan Project and reflects the Participants’ ownership interests therein. This exhibit is to provide the Engineering and Operating Committee, the Auditing Committee, the Fuels Committee and the Coordination Committee with guidelines for carrying out their duties under this Agreement.

6.2.9In areas where ownership of equipment and facilities is not clearly defined by Sections 6.2.1 to 6.2.7, the Engineering and Operating Committee shall make a determination of such ownership in accordance with Section 19. Disputes arising from such determination shall be resolved by the Coordination Committee in accordance with Section 18.

6.2.10Materials and Supplies shall be owned by the Participants in proportion to their respective current investments in the Materials and Supplies.

6.3The Emergency Coal Storage Pile shall be owned by the Participants in accordance with Common Participation Shares.

6.4In the event that a Participant transfers or assigns any of its rights, titles or interests in and to the San Juan Project in accordance with the terms and conditions of this Agreement, the Participants (including the transferee or assignee of a Participant) shall jointly make, execute and deliver a supplement to this Agreement in recordable form which shall describe with particularity and in detail the rights, titles and interests of each Participant following such transfer or assignment.

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6.5PNM and TEP own as tenants in common the Switchyard Facilities described in Exhibit III in equal, undivided one-half (1/2) interests.

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7.0CAPITAL IMPROVEMENTS AND RETIREMENTS OF SAN JUAN PROJECT AND PARTICIPANTS’ SOLELY OWNED FACILITIES:

7.1The Participants recognize that from time to time it may be necessary or desirable to make Capital Improvements to and retirements of facilities comprising the San Juan Project.

7.2Any such Capital Improvements and retirements shall be noted by an appropriate revision in or supplement to the appropriate exhibits hereto attached.

7.3The rights, titles and interests, including Participation Shares, of a Participant in and to any Capital Improvements shall be as provided for the respective classes of property described in Section 6. The Participants shall be obligated for the costs of such Capital Improvements in the same percentages as their Participation Shares.

7.4All Capital Improvements, and a contingency allowance for capital expenditures necessitated by an Operating Emergency or otherwise deemed justifiable by the Operating Agent, shall be included in the annual capital expenditures budget. The Engineering and Operating Committee may authorize Capital Improvements not included in the annual capital expenditures budget; provided, that such Capital Improvements shall not exceed the sum of five hundred thousand dollars ($500,000) for each such Capital Improvement, unless also authorized by the Coordination Committee.

7.5The Operating Agent shall submit to the Participants a forecast of cash requirements by months for Capital Improvements. Said forecast will be submitted on a yearly basis after final budget approvals have been made. A revised forecast shall be submitted when the capital expenditures budget is revised, or when significant changes in

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monthly expenditures from those previously forecast are anticipated. The Operating Agent shall be authorized to make additional expenditures related to Capital Improvements; provided, however, that such additional expenditures for Capital Improvements shall not exceed the sum of one hundred thousand dollars ($100,000) or cause the total expenditure limit contained in the capital expenditures budget to be exceeded, unless also authorized by the Engineering and Operating Committee, or by the Coordination Committee if the total expenditure for such Capital Improvement exceeds five hundred thousand dollars ($500,000).

7.6In the event of the removal or retirement of any facilities comprising part of the San Juan Project, any proceeds realized from the salvage of such facilities shall be distributed to the Participants in accordance with their Participation Shares therein, or shall be applied on account of the Participant’s obligations to pay for Capital Improvements replacing facilities removed or retired. Units of Property retired from service shall be disposed of by the Operating Agent on the best available terms as soon as practicable.

7.7Each Participant shall have the right, at its own expense, to add facilities to the Switchyard Facilities, provided the Engineering and Operating Committee approves the design of such additional facilities and determines that space is available therefor, andthat such committee also determines that such additional facilities will not (i) infringe upon the rights of another Participant in the Switchyard Facilities, (ii) unreasonably interfere with future expansion plans at the San Juan Project, (iii) impair or interfere with the contractual rights of another Participant, or (iv) jeopardize the reliability of another Participant’s system. The Engineering and Operating Committee shall have authority to impose

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conditions on a Participant allowed to make such additions in order to protect the other Participants consistent with applicable rules and regulations of the FERC. Such facilities shall be and remain the sole and exclusive property of the Participant installing same until and unless the Coordination Committee determines that such facilities are necessary and beneficial for operation of the San Juan Project as a whole. In the event of such determination, the facilities shall be acquired as a part of the San Juan Project by the Participants and compensation shall be paid to the selling Participant by the Participants acquiring such interest based on the net book value of such facilities.

7.8Each Participant shall have the right, at its own expense, to add protective relay or communication equipment to facilities solely owned by it, if the Participant determines the protective relay or communication equipment is needed for the protection of its electric system, provided the Engineering and Operating Committee approves the design of such additional equipment and determines that space is available therefor, and that such committee also determines that such additional facilities will not (i) infringe upon the rights of another Participant in the facilities, (ii) unreasonably interfere with future expansion plans at the San Juan Project, (iii) impair or interfere with the contractual rights of another Participant, or (iv) jeopardize the reliability of another Participant’s system.

7.9Transportation and motorized equipment which is to be utilized by the Operating Agent for Operating Work may be purchased or leased by the Operating Agent upon receipt of the approval referred to in Section 19.3.4. Ownership of such purchased equipment and the purchase price thereof shall be allocated between and paid by the Participants in proportion to the percentages established in Section 6. Lease payments made

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by the Operating Agent for such leased equipment shall be apportioned between and paid by the Participants in accordance with Section 22.1. No allowance to the Operating Agent for administrative and general expense shall be included in or added to such lease payments for transportation and motorized equipment which, in lieu of acquiring such equipment by purchase, has been leased on a long-term basis.

7.10Upon retirement of leased transportation and motorized equipment utilized for Operating Work, an amount, which shall be treated as a charge (or credit), shall be determined by multiplying the difference between the salvage value and the unamortized balance owing to the leasing company for each piece of such equipment by a fraction, the numerator of which is the sum of the monthly lease payments for such equipment charged to Operating Work and the denominator of which is the sum of all monthly lease payments made by the Operating Agent for such equipment. Such charge or credit shall be allocated among the Participants in accordance with the applicable percentages set forth in Section 22.

7.11Administrative and general expenses which have been incurred by the Operating Agent which are applicable to authorized Capital Improvements, shall be applied monthly to construction costs incurred during the preceding month. A rate will be developed by the Operating Agent every three (3) years in conjunction with the administrative and general (“A&G”) expenses study referenced in Attachment A to Exhibit VI. The current methodology for calculating the A&G Ratio for Capital Improvements is set forth in Exhibit VI, Attachment E. If any Participant believes that the method used in determining the A&G Ratio for Capital Improvements results in an unreasonable burden on

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such Participant(s), such Participant(s) may request that said method used in determining said ratio be submitted to the Auditing Committee for review in accordance with the procedures set out in Sections 22.6.1 through 22.6.4.

7.12Excluded from the charges in Section 7.11 are expenses incurred under Section 36.2.

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8.0WAIVER OF RIGHT TO PARTITION:

8.1The Participants accept title to their respective interests in the San Juan Project, water rights, lands, land rights and improvements thereon as tenants in common, and agree that their interests therein shall be held in such tenancy in common for the duration of the term of this Agreement, including any extensions thereof. While this Agreement, including any extensions thereof, remains in force and effect, each Participant agrees as follows:

8.1.1That it hereby waives the right to partition the San Juan Project, water rights, lands, land rights or the improvements built thereon (whether by partitionment in kind or by sale and division of the proceeds thereof), and

8.1.2That it will not resort to any action at law or in equity to partition (in either such manner) the San Juan Project, water rights, lands, land rights or the improvements built thereon and waives the benefits of all laws that may now or hereafter authorize such partition.

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9.0BINDING COVENANTS:

9.1Except as otherwise provided in Section 9.3, all of the respective covenants and obligations of each of the Participants set forth and contained in the Project Agreements shall bind and shall be and become the respective obligations of:

9.1.1Each Participant;

9.1.2All mortgagees, trustees and secured parties under all present and future mortgages, indentures and deeds of trust, and security agreements which are or may become a lien upon any of the properties of each Participant;

9.1.3All receivers, assignees for the benefit of creditors, bankruptcy trustees and referees of a Participant;

9.1.4All other persons, firms, partnerships or corporations claiming through or under any of the foregoing; and

9.1.5Any successors or assigns of any of those mentioned in Sections 9.1.1 to 9.1.4, inclusive,

and shall be obligations running with the Participants’ rights, titles and interests in the San Juan Project, with all of the rights, titles and interests (if any) of each Participant in, to and under this Agreement and with their rights, titles and interests in the water rights, lands, land rights and the improvements thereon. It is the specific intention of this provision that all of such covenants and obligations shall be binding upon any party which acquires any of the rights, titles and interests of any of the Participants in the San Juan Project, in, to and under this Agreement, and/or in the water rights, lands, land rights or the improvements thereon, and that all of the above-described persons and groups shall be obligated to use such Participant’s rights, titles and interests in the San Juan Project, in, to and under this Agreement, and in the water rights, lands, land rights and the improvements thereon, for the purpose of discharging its covenants and obligations under this Agreement.

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9.2The rights, titles and interests of each Participant in the San Juan Project, its rights, titles and interests in, to and under this Agreement and its rights, titles and interests in and to the water rights, lands, land rights and improvements thereon, shall inure to the benefit of its successors and assigns.

9.3Any mortgagee, trustee or secured party, or any receiver or trustee appointed pursuant to the provisions of any present or future mortgage, deed of trust, indenture or security agreement creating a lien upon or encumbering the rights, titles or interests of any Participant in the San Juan Project, in, to and under this Agreement and/or in the water rights, lands, land rights or the improvements thereon, and any successor thereof by action of law or otherwise, and any purchaser, transferee or assignee of any thereof, shall not be obligated to pay any monies accruing on account of any of the obligations or duties of such Participant under this Agreement incurred prior to the taking of possession or the initiation of foreclosure or other remedial proceedings by such mortgagee, trustee or secured party.

9.4In the event that any or all of the provisions of this Section 9 shall not be legally effective as to any Participant, or its mortgagees, trustees, secured parties, receivers, successors or assigns, then such Participant shall not be deemed in violation of this Section 9 by reason thereof.

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9.5Nothing in this Section 9 or in this Agreement shall be deemed to change any rights, titles or interests to water rights, lands, land rights and the improvements thereon.

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10.0MORTGAGE AND TRANSFER OF PARTICIPANTS’ INTERESTS:

10.1The Participants shall have the right at any time and from time to time to mortgage, create or provide for a security interest in or convey in trust their respective rights, titles and interests in the San Juan Project, their respective rights, titles and interests in, to and under a Project Agreement and/or their rights, titles and interests in the water rights, lands, land rights or the improvements to be built thereon to a trustee or trustees under deeds of trust, mortgages or indentures, or to secured parties under a security agreement, as security for their present or future bonds or other obligations or securities, and to any successors or assigns thereof without need for the prior consent of the other Participants, and without such mortgagee, trustee or secured party assuming or becoming in any respect obligated to perform any of the obligations of the Participants.

10.2Any mortgagee, trustee or secured party under present or future deeds of trust, mortgages, indentures or security agreements of any of the Participants and any successor or assign thereof, and any receiver, referee, or trustee in bankruptcy or reorganization of any of the Participants, and any successor by action of law or otherwise, and any purchaser, transferee or assignee of any thereof may, without need for the prior consent of the other Participants, succeed to and acquire all the rights, titles and interests of such Participant in the San Juan Project, in, to and under the Project Agreements and/or the rights, titles and interests of such Participant in the water rights, lands, land rights and improvements thereon, and may take over possession of or foreclose upon said property, rights, titles and interests of such Participant.

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10.3Except as otherwise provided in Sections 10.1, 10.2 or 10.4 or, with respect to a transfer or assignment by a Participant to another Participant as provided in Section 11, no Participant shall transfer or assign its respective rights, titles and interests in the San Juan Project, in, to and under this Agreement and/or in the water rights, land, land rights and the improvements thereon, without the prior written consent of the other Participants, which consent shall not be unreasonably withheld.

10.4Each Participant shall have the right to transfer or assign its respective rights, titles and interests in the San Juan Project, in, to and under this Agreement and/or in the water rights, land, land rights and the improvements thereon, without the need for prior consent of the other Participants, at any time to any of the following:

10.4.1To any corporation or other entity acquiring all or substantially all of the property of such Participant; or

10.4.2To any corporation or entity into which or with which such Participant may be merged or consolidated; or

10.4.3To any corporation or entity the stock or ownership of which is wholly owned by a Participant; or

10.4.4To any corporation or other entity which owns all of the outstanding common stock or other ownership interest of a Participant (its “Parent”); or

10.4.5To any corporation or other entity the common stock or other ownership interest of which is wholly owned by the Parent of a Participant.

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10.5Except as otherwise provided in Sections 10.1, 10.2 and 9.3, any successor to the rights, titles and interests of a Participant in the San Juan Project, to the rights, titles and interests of a Participant in, to and under the Project Agreements and/or in the water rights, lands, land rights or improvements thereon shall assume and agree to fully perform and discharge all of the obligations hereunder of such Participant, and such successor shall notify the other Participants in writing of such transfer, assignment or merger, and shall furnish to the other Participants evidence of such transfer, assignment or merger. Any such successor shall specifically agree in writing with the remaining Participants at the time of such transfer, assignment or merger that it will not transfer or assign any rights, titles and interests acquired from the assigning Participant without complying with the terms and conditions of Section 11.

10.6No Participant shall be relieved of any of its obligations and duties to the other Participants by a transfer, assignment or merger under this Section 10 without the express prior written consent of the remaining Participants, which consent shall not be unreasonably withheld.

10.7Except as otherwise provided in Section 10.5, any transfer, assignment or merger made pursuant to the provisions of this Section 10 shall not be subject to the terms and conditions set forth and contained in Section 11.

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11.0RIGHTS OF FIRST REFUSAL:

11.1The purpose of this Section 11 is to set forth the manner in which all existing or future rights of first refusal, pertaining to the transfer of interests in the San Juan Project, shall be exercised. Except as provided in Section 10, PNM has a right of first refusal with respect to the proposed transfer of any ownership interest in the San Juan Project by any Participant and TEP has a right of first refusal with respect to PNM’s proposed transfer of an interest in Unit 1 or Unit 2 and associated common property. The existence of other rights of first refusal shall be as provided in other instruments to which Participants are parties. Nothing in this Section 11 shall be construed to limit or expand the rights of first refusal of any Participant.

11.2Except as provided in Section 10, should a Participant desire to assign, transfer, convey or otherwise dispose of (hereinafter collectively referred to as “Assign”) its rights, titles and interests in the San Juan Project, or its rights, titles and interests in, to and under the Project Agreements, or its rights, titles and interests in the water rights, lands, land rights or the improvements thereon or any part thereof or interest therein (hereinafter referred to as “Transfer Interest”), to any person, company, corporation or governmental agency (hereinafter referred to as “Outside Party”), the Participant desiring to Assign shall first make an offer to sell the Transfer Interest to a Participant(s) having a right of first refusal, on the basis of the applicable amount as set out in either Section 11.2.1 or Section 11.2.2:

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11.2.1Where the Outside Party proposes to purchase for a specified monetary amount, from the Participant desiring to Assign, an interest only in the San Juan Project and/or in contract rights, water rights, lands, land rights and improvements associated therewith, the amount of (i) a bona fide written offer from an Outside Party ready, willing and able (subject to obtaining any required regulatory approvals) to purchase the Transfer Interest; or, in the absence of a bona fide written offer, (ii) a purchase price set out in a bona fide purchase and sale agreement between the Participant desiring to Assign and an Outside Party ready, willing and able (subject to obtaining any required regulatory approvals) to purchase the Transfer Interest; or

11.2.2Where the Outside Party proposes to purchase from the Participant desiring to Assign, (i) as part of a non-monetary offer (such as in the case of an asset swap) or (ii) when a segregated value for the Transfer Interest is not available (such as in the case of a bundled or packaged sale of assets), or (iii) where the Outside Party proposes to purchase an interest not only in the San Juan Project and/or in contract rights, water rights, lands, land rights and improvements associated therewith, but also in other property of the Participant desiring to Assign, the fair market value of the Transfer Interest. As used herein, the term “fair market value” means the amount of money which a purchaser, willing but not obligated to buy the property, will pay to an owner, willing but not obligated to sell it, taking into consideration all of the uses to which the Transfer Interest is adapted and might in reason be applied.

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11.3At least three (3) months prior to its intended date to Assign, and after its receipt of a bona fide written offer, or execution of a bona fide purchase and sale agreement, of the type described in Section 11.2, the Participant desiring to Assign its Transfer Interest shall serve written notice of its intention to do so upon the Participant(s) having a right of first refusal, in accordance with Section 42. Such notice shall: (i) have attached as an exhibit a copy of the bona fide offer of an Outside Party or of the bona fide purchase and sale agreement between the Outside Party and the Participant desiring to Assign (an “Outside Offer”); and (ii) shall contain a statement of the approximate proposed date to Assign.

11.4The Participant(s) having the right of first refusal shall signify its (their) desire to purchase the entire Transfer Interest, or not purchase the entire Transfer Interest, by serving written notice of its (their) intention upon the Participant desiring to Assign pursuant to Section 42 within sixty (60) days after such service pursuant to Section 11.3 of the written notice of intention to Assign. Failure by a Participant to serve notice as provided hereunder within the time period specified shall be conclusively deemed to be notice of its intention not to purchase the Transfer Interest.

11.5When intention to purchase the entire Transfer Interest has been indicated by notices duly given hereunder by the Participant(s) desiring to purchase the Transfer Interest, the affected Participants shall thereby incur the following obligations:

11.5.1The Participant desiring to Assign and a Participant desiring to purchase the Transfer Interest shall be obligated to proceed in good faith and with diligence to obtain all required authorizations and approvals to Assign;

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11.5.2The Participant desiring to Assign shall be obligated to obtain the release of any liens imposed by or through it upon any part of the Transfer Interest and to Assign the Transfer Interest at the earliest practicable date thereafter; and

11.5.3A Participant desiring to purchase the Transfer Interest shall be obligated to perform all terms and conditions required of it to complete the purchase of the Transfer Interest.

The purchase of the Transfer Interest shall be fully consummated within six (6) months following the date upon which all notices required to be given under this Section 11 have been duly served, unless the Participant is then diligently pursuing applications to appropriate regulatory bodies (if any) for required authorizations to effect such assignment or is then diligently prosecuting or defending appeals from orders entered or authorizations issued in connection with such applications.

11.6If the intention to purchase the entire Transfer Interest has not been indicated by notices given within the time periods specified in this Section 11 by a Participant desiring to purchase the Transfer Interest, the Participant desiring to Assign shall be free to Assign all, but not less than all, of its Transfer Interest to the Outside Party that made the Outside Offer, upon the terms and conditions set forth in the Outside Offer. If such assignment of the entire Transfer Interest to the Outside Party is not completed within three (3) years after the approximate proposed date to Assign specified in the notice given pursuant to Section 11.3, the Participant desiring to Assign its Transfer Interest must, unless it is then diligently pursuing its applications to appropriate regulatory bodies (if any) for required authorizations to effect such assignment, or is then diligently prosecuting or

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defending appeals from orders entered or authorizations issued in connection with such applications, give another complete new right of first refusal to the Participant(s) desiring to purchase pursuant to the provisions of this Section 11, before such Participant shall be free to Assign a Transfer Interest to said Outside Party.

11.7No assignment of a Transfer Interest, whether to another Participant or to an Outside Party, shall relieve the assigning Participant from full liability and financial responsibility for performance after any such assignment: (i) of all obligations and duties incurred by such Participant prior to such assignment under the terms and conditions of the Project Agreements; and/or (ii) of all obligations and duties provided and imposed after such assignment upon such assigning Participant under the terms and conditions of the Project Agreements, unless and until the assignee shall agree in writing with the remaining Participants to assume the obligations and duties of a Participant hereunder; provided further, however, that such assignor shall not be relieved of any of its obligations and duties by an assignment under this Section 11, without the express prior written consent of the remaining Participants, which consent shall not be unreasonably withheld.

11.8Any transferee, successor or assignee, or any party who may succeed to the Transfer Interest pursuant to this Section 11, shall specifically agree in writing with the remaining Participants at the time of such transfer or assignment that it will not transfer or assign all or any portion of the Transfer Interest so acquired without complying with the terms and conditions of this Section 11.

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11.9The provisions of Section 11.8 shall not be applicable to any assignment of a Transfer Interest by one Participant to another Participant, provided that payment in full of such Transfer Interest, as defined in Section 11, has been made by the Participant who is the assignee thereof.

11.10A Participant may, for the purpose of financing its interest in pollution control systems and facilities at the San Juan Project, sell, transfer or convey such interests pursuant to the New Mexico Pollution Control Revenue Bond Act, and any such sale, transfer or conveyance shall not be deemed as an assignment, transfer, conveyance or other disposal within the meaning of this Section 11.

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12.0RIGHTS OF PNM AND TEP IN WATER AND COAL:

12.1If, pursuant to the terms and conditions of the Underground Coal Sales Agreement, or the sublease dated August 18, 1980 (as amended to date and as such sublease may be amended from time to time), between Western Coal Company and Utah International, Inc. or their successors (“Sublease”), PNM and TEP succeed to any interest in coal lands, coal leases, water rights, or other property, the rights, titles and interests of PNM and TEP therein shall be held as tenants in common, with each of PNM and TEP having an equal undivided one-half (1/2) interest therein, and such rights, titles and interests shall be subject to all the terms and conditions set forth and contained in this Agreement.

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13.0SEVERANCE OF IMPROVEMENTS:

13.1All facilities, structures, improvements, equipment and property of whatever kind and nature constructed, placed or affixed on the rights-of-way, easements, patented lands, fee lands and leased lands as part of, or as Capital Improvements, to the San Juan Project, as against all parties and persons whomsoever (including, without limitation, any party acquiring any interest in the rights-of-way, easements, patented, fee or leased lands or any interest in or lien, claim or encumbrance against any of such facilities, structures, improvements, equipment and property of whatever kind and nature) shall be deemed to be and remain personal property of the Participants, not affixed to the realty.

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PART III

ENTITLEMENTS TO OUTPUT OF SAN JUAN PROJECT

14.0ENTITLEMENT TO CAPACITY AND ENERGY:

14.1Subject to the provisions of Section 16, the Participants shall be entitled to the Net Effective Generating Capacity of each of Unit 1, Unit 2, Unit 3 and Unit 4 in proportion to their respective Participation Shares. Each Participant shall be entitled to schedule its Energy up to the Available Operating Capacity.

14.2The Operating Agent shall keep the system dispatcher of each Participant advised of the Available Operating Capacity.

14.3When a Participant’s request for its share of the Available Operating Capacity necessitates the operation of a Unit, each Participant shall schedule for its account not less than its share of Minimum Net Generation. If, however, a Participant has scheduled an amount of Energy in excess of its share of the Minimum Net Generation, the other Participants shall be allowed to reduce their scheduled Energy to an amount that will maintain the Unit at the Minimum Net Generation level.

14.4The delivery of Energy from the San Juan Project shall be scheduled by each Participant in advance with the Operating Agent and accounted for on the basis of integrated hourly actual generation, all in accordance with any operating procedures which may be established or approved by the Engineering and Operating Committee. Such operating procedures shall provide for modifying such schedules to meet the needs of day-to-day and hour-by-hour operation, including emergencies on a Participant’s system.

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14.5The Operating Agent shall, to the extent possible, generate Energy at the San Juan Project in accordance with schedules submitted by each Participant, as such schedules may be revised from time to time, as long as such schedules do not jeopardize the operation of the San Juan Project.

14.6The Participants shall revise their schedules in the event of an Operating Emergency or other incident beyond the control of the Operating Agent to reflect the actual Energy available from the San Juan Project during the period of the Operating Emergency or incident.

14.7The Energy generated at the San Juan Project shall be controlled within PNM’s Control Area; provided, that such control shall not diminish the rights of any Participant to receive its entitlement of Energy from the San Juan Project.

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15.0CAPACITY ALLOCATION OF SWITCHYARD FACILITIES:

15.1The electrical capacity in the Switchyard Facilities shall be made available to PNM and TEP in the manner and in the amounts as set forth in Section 6.2.7. For the purposes of this Agreement, the FC Line shall be considered a part of the Switchyard Facilities.

15.1.1The transmission capacity of the FC Line shall measured at the Four Corners terminal. PNM and TEP each shall be entitled to fifty percent (50%) of the designated FC Line Capacity.

15.1.2The transmission capacity of the FC Line termination and other contract matters concerning the Four Corners Project shall be handled individually by PNM and TEP.

15.2The points of attachment to the San Juan 345 kV Switchyard Facilities for the purposes of this Section 15 are:

No. 1: TEP/PNM No. 1 345 kV transmission line;

No. 2: TEP/PNM No. 2 345 kV transmission line;

No. 3: PNM/TEP Four Corners Generating Plant 345 kV switchyard (through the FC Line);

No. 4: PNM’s WW 345 kV transmission line;

No. 5: PNM’s OJ 345 kV transmission line;

No. 6:Colorado Public Service Company/Western Area Power Administration/Tri-State Rifle 345 kV transmission line;

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No. 7:Western Area Power Administration-Shiprock 345 kV transmission line.

15.2.1 The Participants collectively shall not schedule more Power and Energy through any of the foregoing individual points of attachment than the established rating of that facility.

15.2.2The Participants’ individual transmission capacity rights into or out of the Switchyard Facilities attachment points shall be the same as the ownership or contract rights of the Participant(s) in the attached facility up to the limits specified in this Section 15.

15.2.3Any transmission capacity in the Switchyard Facilities specified to be available in Section 15.2.1 or otherwise determined to be available by the Engineering and Operating Committee, but not allocated to the individual Participants under Section 15.2.2, shall be declared “excess capacity” by the Engineering and Operating Committee. The Engineering and Operating Committee shall allocate such excess transmission capacity to PNM or TEP or such Participants having an ownership interest in the Switchyard Facilities, upon request in the amount requested for specified periods of time to the extent and for such time as the Engineering and Operating Committee finds such excess capacity to be available. 

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16.0USE OF FACILITIES DURING CURTAILMENTS:

16.1If the Net Effective Generating Capacity of all Units is reduced because of factors (including, but not limited to, equipment failures, scheduled or unscheduled outages, fuel or fuel deliveries, water supply, air quality limitations) which commonly influence the total output of all Units, each Participant’s entitlement to Capacity during such period shall be reduced in proportion to the percentages specified in Section 6.2.6 during each hour of such curtailment unless otherwise specified in a separate agreement.

16.2If factors which influence the operation of a Unit cause a curtailment of that Unit, then the capacity entitlement from that Unit for each Participant in that Unit shall be in proportion to the Participant’s Participation Share of that Unit.

16.3If, because of factors which influence the operation solely of Units 1 and 2, or solely of Units 3 and 4, there shall be a curtailment of Units 1 and 2, or of Units 3 and 4, as the case may be, the curtailment for each Participant in Units 1 and 2, or Units 3 and 4, shall be allocated in proportion to the percentages specified in Sections 6.2.4 and 6.2.5, respectively.

16.4To the extent that a curtailment results from scarcity of resources and not from mechanical or legal limitations, Participants may agree in writing to modify their schedules to allocate the use of such resources to such Unit(s) or to such times as to make the most efficient use thereof, consistent with Prudent Utility Practice, during the pendency of such curtailment. Notwithstanding the provisions of Section 23.2, the Operating Agent shall, during such curtailments, account for coal inventory on a Participant by Participant basis. Upon the conclusion of such curtailment, the provisions of Section 23.2 shall apply to any remaining coal inventory.

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16.5Curtailment of the transmission capacity in the Switchyard Facilities shall be allocated to the Participants in the manner and in the amounts as set forth in Section 6.2.7.

16.6No Participant shall exercise its rights relating to the San Juan Project so as to endanger or unreasonably interfere with the operation of the San Juan Project or the right of any other Participant to use its share of Capacity and Energy from the San Juan Project.

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17.0START-UP AND AUXILIARY POWER AND ENERGY REQUIREMENTS:

17.1Each Participant shall be obligated to provide its Participation Share of the Energy requirements to start up and operate each Unit, and such requirements shall be provided by the Participants based upon the Participant’s percentage of operating costs in accordance with Section 22.1. Appropriate metering facilities shall be installed to assure measurement of such Energy. Such requirements for Energy shall be scheduled in advance by the Operating Agent in accordance with operating procedures approved by the Engineering and Operating Committee.

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PART IV

ADMINISTRATION

18.0COORDINATION COMMITTEE:

18.1As a means of securing effective cooperation and interchange of information and of providing consultation on a prompt and orderly basis among the Participants in connection with various administrative and technical problems which may arise from time to time under this Agreement, the Coordination Committee shall remain in existence during the term of this Agreement. Except as otherwise expressly provided in this Agreement, the Coordination Committee shall have no authority to modify any of the provisions of this Agreement.

18.2The Coordination Committee shall consist of one representative from each Participant who shall be an officer or other duly authorized representative of a Participant. Any of the Participants may designate an alternate or substitute to act as its representative on the Coordination Committee in the absence of the regular representative on the Coordination Committee or to act on specified occasions or with respect to specified matters. Each Participant shall notify the other Participants promptly, in writing, of the designation of its representative and alternate representative on the Coordination Committee and of any subsequent changes in such designations. The chairperson of the Coordination Committee shall be a representative employed by the Operating Agent.

18.3The Coordination Committee shall have the following functions and responsibilities:

18.3.1Provide liaison between and among the Participants.

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18.3.2Exercise general supervision over the Engineering and Operating Committee, the Fuels Committee and the Auditing Committee.

18.3.3Consider and act upon all matters referred to the Coordination Committee by the Engineering and Operating Committee, the Fuels Committee and the Auditing Committee.

18.4Any action or determination of the Coordination Committee shall require a vote of the Participants in accordance with Sections 18.4.1, 18.4.2 or 18.4.3. A Participant’s Coordination Committee representative shall be entitled to vote on all matters except those actions or determinations which relate solely to a Unit or to common property in which such Participant does not have a Participation Share or as provided in Section 35.4.1. If a Participant’s right to vote has been suspended pursuant to Section 35.4.1, the requisite majorities for actions or determinations specified in Sections 18.4.1, 18.4.2 and 18.4.3 shall be adjusted in proportion to the number of Participants whose right to vote has not been suspended. An example of such an adjustment is provided in Exhibit VIII, attached hereto and incorporated herein. Maintenance scheduling and operation during periods of curtailment of the total San Juan Project are not matters which relate solely to a Unit, but are deemed to be matters affecting all Units.

18.4.1Except as provided in Sections 18.4.2 and 18.4.3, any actions or determinations brought before the Coordination Committee shall require the following vote:

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(a)More than a sixty-six and two thirds percent (66 2/3%) majority of the Participation Shares of the Participants in a Unit or common property as defined in Section 6.2; and

(b)More than a sixty-six and two thirds percent (66 2/3%) majority of the number of individual Participants having a Participation Share in a Unit or common property as defined in Section 6.2.

18.4.2Any action or determination of the Coordination Committee related to common property as set forth in Section 6.2.6 and involving an expenditure greater than five million dollars ($5,000,000) shall require the following vote:

(a)More than an eighty-two percent (82%) majority of the Common Participation Shares of the Participants; and

(b)A minimum of sixty-six and two thirds percent (66 2/3%) majority of the number of the individual Participants.

18.4.3 Any action or determination of the Coordination Committee regarding any amendment of the Underground Coal Sales Agreement, replacement of the Underground Coal Sales Agreement with a new agreement or any interim coal pricing agreement related to the Underground Coal Sales Agreement (or its successor) shall require the following vote:

(a)More than an eighty-two percent (82%) majority of the Common Participation Shares of the Participants; and

(b)A minimum of sixty-six and two thirds percent (66 2/3%) majority of the number of individual Participants.

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18.5The Coordination Committee shall keep written minutes and records of all meetings. Any action or determination made by the Coordination Committee shall be reduced to writing and shall become effective when signed by the representatives of the Participants entitled to vote thereon, representing a voting majority of the members of the Coordination Committee, as defined in Section 18.4; provided, however, in the event of an Operating Emergency, actions or determinations may be made on the basis of oral agreements among duly authorized representatives of the respective Participants entitled to vote thereon, and such action or determination subsequently shall be reduced to writing. Coordination Committee representatives may, by prior arrangement with the chairperson of the Coordination Committee, attend a meeting of the Coordination Committee by conference call or video conferencing. A Coordination Committee representative who is unable to attend a meeting of the Coordination Committee may vote in absentia by delivering to the chairperson of the Coordination Committee, at least twenty-four (24) hours prior to the scheduled commencement of the meeting, a written statement, including by e-mail or facsimile, identifying the matter to be voted on and how the representative desires to vote.

18.6Except for matters subject to the voting requirements of Section 18.4.3, in the event the Coordination Committee fails to reach agreement on any matter, which such committee is authorized to determine, approve or otherwise act upon after a reasonable opportunity to do so, then the Operating Agent shall be authorized and obligated to take such reasonable and prudent action, consistent with Prudent Utility Practice, as is necessary to the successful and proper operation and maintenance of the San Juan Project, pending the resolution, by arbitration or otherwise, of any such inability or failure to agree.

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18.7In the event the Coordination Committee fails to reach agreement on a matter subject to the voting requirements of Section 18.4.3, then an impasse shall be deemed to exist and the Participants which are signatories to the Underground Coal Sales Agreement then in effect shall have the obligation and the responsibility, consistent with Prudent Utility Practice, to maintain a supply of coal to the San Juan Project.

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19.0ENGINEERING AND OPERATING COMMITTEE:

19.1The Engineering and Operating Committee shall remain in existence during the term of this Agreement. Except as expressly provided in this Agreement, the Engineering and Operating Committee shall have no authority to modify any of the provisions of this Agreement.

19.2The Engineering and Operating Committee shall consist of up to two representatives from each Participant who shall collectively have one vote. Any of the Participants may designate an alternate or substitute to act as its representative on the Engineering and Operating Committee in the absence of a regular representative on the Engineering and Operating Committee or to act on specified occasions or with respect to specified matters. Each Participant shall notify the other Participants promptly, in writing, of the designation of its representatives and alternate representative on the Engineering and Operating Committee and of any subsequent change in the designation. The chairperson of the Engineering and Operating Committee shall be a representative employed by the Operating Agent.

19.3The Engineering and Operating Committee shall have the following functions and responsibilities:

19.3.1Review and approve the following items related to the performance of Operating Work.

19.3.1.1Capital Improvements and the annual Capital Improvements budget.

19.3.1.2The annual staffing table.

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19.3.1.3The annual operation and maintenance budget.

19.3.1.4Such written statements of operating or maintenance procedures as may be submitted to the Engineering and Operating Committee.

19.3.1.5The planned annual maintenance schedule.

19.3.1.6The policies for establishing the Emergency Spare Parts inventory.

19.3.1.7The policies for establishing the inventory for Materials and Supplies.

19.3.1.8The statistical and administrative reports, budgets and information and other similar records, and the form thereof, to be kept and furnished by the Operating Agent, in accordance with Section 28.3.15 (excluding accounting records used internally by the Operating Agent for the purpose of accumulating financial and statistical data, such as books of original entry, ledgers, work papers and source documents).

19.3.1.9The determination of Net Effective Generating Capacity, Minimum Net Generation and Net Energy Generation of the San Juan Project, based upon recommendations of the Operating Agent.

19.3.1.10The principles and procedures for establishing communication channels among Participants.

19.3.1.11The operating procedures for performance and efficiency testing.

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19.3.1.12The operating procedures for maintaining complete and accurate Capacity and Energy accounting.

19.3.1.13The Operating Agent’s estimate and analysis of the total expenditures resulting from an Operating Emergency, as provided in Section 29.7.

19.3.1.14The results and expenditures of programs and contracts on environmental control and data collection for which the Operating Agent has contracted.

19.3.2Establish procedures for the operation of the San Juan Project during any period of curtailed operations which reduces or may reduce the Net Effective Generating Capacity.

19.3.3Except for an Operating Emergency, as provided in Section 29, designate a construction agent responsible for the design, construction and acquisition of Capital Improvements.

19.3.4Approve the list of transportation and motorized equipment to be purchased or leased by the Operating Agent for use in the performance of Operating Work.

19.3.5Perform such other functions and responsibilities as may be assigned to it from time to time by the Coordination Committee.

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19.4 Any action or determination of the Engineering and Operating Committee shall require a vote of the Participants, in the manner provided for in Sections 18.4.1 and 18.4.2. A Participant’s Engineering and Operating Committee voting representative shall be entitled to vote on all matters except those actions or determinations which relate solely to a Unit or to common property in which such Participant does not have a Participation Share or as provided in Section 35.4.1. If a Participant’s right to vote has been suspended pursuant to Section 35.4.1, the requisite majorities for actions or determinations specified in Sections 18.4.1 and 18.4.2 shall be adjusted in proportion to the number of Participants whose right to vote has not been suspended. An example of such an adjustment is provided in Exhibit VIII. Maintenance scheduling and operation during periods of curtailment of the total San Juan Project are not matters which relate solely to a Unit, but are deemed to be matters affecting all Units.

19.5The Engineering and Operating Committee shall keep written minutes and records of all meetings. Any action or determination made by the Engineering and Operating Committee shall be reduced to writing and shall become effective when signed by the representatives of the Participants entitled to vote thereon, representing a voting majority of the members of the Engineering and Operating Committee, as defined in Section 19.4; provided, however, in the event of an Operating Emergency, actions or determinations may be made on the basis of oral agreements among duly authorized representatives of the respective Participants entitled to vote thereon, and such action or determination subsequently shall be reduced to writing. Engineering and Operating Committee representatives may, by prior arrangement with the chairperson of the Engineering and Operating Committee, attend a meeting of the Engineering and Operating Committee by conference call or video conferencing. An Engineering and Operating Committee representative who is unable to attend a meeting of the Engineering and Operating Committee may vote in absentia by delivering to the chairperson of the Engineering and Operating Committee, at least twenty-four (24) hours prior to the scheduled commencement of the meeting, a written statement, including by e-mail or facsimile, identifying the matter to be voted on and how the representative desires to vote.

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19.6In the event that less than a requisite majority of the Engineering and Operating Committee is obtained, the matter shall be referred to the Coordination Committee for decision upon the request of any Participant’s Engineering and Operating Committee representative.

19.7In the event the Engineering and Operating Committee fails to reach agreement on any matter which such committee is authorized to determine, approve or otherwise act upon after a reasonable opportunity to do so, then the Operating Agent shall be authorized and obligated to take such reasonable and prudent action, consistent with Prudent Utility Practice, as is necessary to the successful and proper operation and maintenance of the San Juan Project, pending the resolution, by arbitration or otherwise, of any such inability or failure to agree.

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20.0FUELS COMMITTEE:

20.1As a means of establishing a centralized forum to facilitate the timely and candid consideration and discussion between all Participants of policies and issues associated with the procurement of coal for the San Juan Project, there is hereby established a Fuels Committee, which shall remain in existence during the term of this Agreement. The Participants do not intend that the operation of the Fuels Committee shall affect the day-to-day fuels-related operational responsibilities of the Operating Agent, except as otherwise specifically provided in this Section 20. TheFuels Committee shall have no authority to modify any of the provisions of this Agreement.

20.2The Fuels Committee shall consist of one representative from each Participant. Any of the Participants may, by written notice to the other Participants, designate an alternate or substitute to act as its representative on the Fuels Committee in the absence of the regular representative on the Fuels Committee or to act on specified occasions or with respect to specified matters. Each Participant shall notify the other Participants promptly in writing of the designation of its representative on the Fuels Committee and of any subsequent change in such designation. The chairperson of the Fuels Committee shall be a representative employed by a Participant that is a signatory to the Underground Coal Sales Agreement. The Fuels Committee shall meet regularly, but in no event less than semiannually. Special meetings shall be called by the chairperson if requested in writing by any three (3) Participants.

20.3The Fuels Committee shall have the following functions and responsibilities:

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20.3.1To conduct studies, or cause studies to be conducted, regarding criteria pertaining to the acquisition of coal supplies and the negotiation and approval of coal agreements. Such studies and recommendations may include, but are not limited to:

20.3.1.1Annual fuel supply budgets

20.3.1.2Coal cost

20.3.1.3Coal delivery rates and minimum take obligations

20.3.1.4Coal quality

20.3.1.5Contract terms

20.3.1.6Economic requirements

20.3.1.7Negotiation strategies

20.3.1.8Potential coal suppliers

provided, however, that prior to any such study being conducted, the Participant(s) desiring that the study be performed shall have made suitable arrangements therefor, including payment arrangements with the provider of thestudy. Nothing in this Section 20.3 shall be construed to require the Operating Agent or any Participant which is a signatory to the Underground Coal Sales Agreement to undertake any uncompensated or unfunded study which it would not otherwise perform.

20.3.2To obtain input from all Participants regarding individual criteria and economic requirements necessary to vote on matters entrusted to the Fuels Committee or to make collective recommendations to the Coordination Committee.

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20.3.3To approve Participant Monthly Minimum Tons delivery schedules and pricing pursuant to Annual Interim Invoicing Agreements as defined in Section 8.7 of the Underground Coal Sales Agreement.

20.3.4To receive progress reports from and provide recommendations to negotiators acting on behalf of Participants in the negotiation and administration of coal supply and related agreements.

20.3.5To provide regular progress reports to the Engineering and Operating and to the Coordination Committees, as requested by such committees.

20.3.6To establish the amount of coal to be maintained in the Emergency Coal Storage Pile.

20.3.7To establish operating procedures for delivery of coal to the Emergency Coal Storage Pile.

20.3.8 To establish procedures for the determination of Participant Coal Consumption.

20.3.9To perform such other functions and responsibilities as are identified in Sections 23.4.2.8, and 23.4.2.10.

20.3.10 To perform such other functions and responsibilities as may be assigned to it from time to time by the Coordination Committee.

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20.4The following special procedures shall apply to all negotiations or discussions with SJCC regarding amendment, interim pricing agreements, termination or succession of the Underground Coal Sales Agreement, related agreements, or with any other coal supplier or potential supplier. No Fuels Committee representative or Participant shall engage in bilateral negotiations or discussions concerning coal supply or related matters for the San Juan Project with SJCC or any other coal supplier or potential supplier; provided, however, that nothing herein shall be construed to prevent the Operating Agent or the Participants which are signatories to the Underground Coal Sales Agreement, in the conduct of its or their day-to-day operational responsibilities, from performing Operating Work, engaging in business contacts and communications with SJCC or other coal suppliers or potentialsuppliers to the San Juan Project or in the administration of the Underground Coal Sales Agreement and related agreements.

20.4.1Each Participant which is a signatory to the Underground Coal Sales Agreement shall be entitled to have at least two (2) representatives present at any such negotiations or discussions. Participants not signatories to the Underground Coal Sales Agreement or its successors (for purposes of this Section 20.4.1, the “Remaining Participants”) shall have the collective right to have two (2) representatives present at any such negotiations or discussions. The Remaining Participants may jointly or separately designate representatives, but in no case may the total number of representatives so designated by all of the Remaining Participants exceed two (2). Any dispute among the Remaining Participants regarding the naming of representatives shall be subject to resolution pursuant to Section 37 and shall not restrict the rights of any other representatives to engage in any ongoing negotiations or discussions. Representatives shall be

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designated in writing by the Participants which are signatories to the Underground Coal Sales Agreement and Remaining Participants. If such representatives are not employees of a Participant or a Remaining Participant, such fact shall be disclosed in writing to all Participants and Remaining Participants. Representatives shall agree in writing to: (i) avoid any conflict of interest that would be detrimental to the operation of the San Juan Project; and (ii) maintain all proprietary information obtained through such negotiations and discussions in confidence. The form of such confidentiality agreements shall be prepared by the Fuels Committee, and shall be subject to the approval of the Participants which are signatories to the Underground Coal Sales Agreement, such approval not to be unreasonably withheld. Such confidentiality agreements shall be executed by a Participant’s Coordination Committee representative or, as appropriate, the person authorized by such Participant or Representative to execute such documents. Representatives may be changed by Participants or Remaining Participants by the giving of written notice to all other Participants and Remaining Participants.

20.4.2Representatives shall make regular reports to, coordinate with, and obtain the recommendations of the Fuels Committee regarding the progress of and issues involved in such coal negotiations or discussions.

20.5Any proposed action or determination regarding any amendment of the Underground Coal Sales Agreement, replacement of the Underground Coal Sales Agreement with a new agreement or any interim or other annual coal pricing agreement related to the Underground Coal Sales Agreement (or its successor) or any other action or

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determination of the Fuels Committee shall be submitted to the vote of the representatives of the Participants on the Fuels Committee. Any such action or determination shall require the affirmative vote as established in Section 18.4.3, except that if a Participant’s right to vote has been suspended pursuant to Section 35.4.1, the requisite majority for actions or determinations specified in Section 18.4.3 shall be adjusted in proportion to the number of Participants whose right to vote has not been suspended. An example of such an adjustment is provided in Exhibit VIII.

20.5.1If, upon such vote, the requisite votes are obtained, the Participants which are signatories to the Underground Coal Sales Agreement then in effect or the Operating Agent, as applicable, shall proceed in accordance with the affirmative vote of the Fuels Committee without further action of any other San Juan Project committee.

20.5.2If, upon such vote, the requisite votes are not obtained, the matter giving rise to the vote shall, not later than thirty (30) days after the negative vote of the Fuels Committee, be submitted to the Coordination Committee for its vote in accordance with Section 18. If the requisite majorities are obtained in the Coordination Committee vote, the Participants which are signatories to the Underground Coal Sales Agreement then in effect or the Operating Agent, as applicable, shall proceed in accordance with the affirmative vote of the Coordination Committee.

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20.5.3If the requisite votes are not obtained in the Coordination Committee vote, then consistent with Section 18.7, the Participants which are signatories to the Underground Coal Sales Agreement then in effect or the Operating Agent, as applicable, shall have the obligation and the responsibility, consistent with Prudent Utility Practice, to maintain a supply of coal to the San Juan Project.

20.6The Fuels Committee shall keep written minutes and records of all meetings. Any action or determination made by the Fuels Committee shall be reduced to writing and shall become effective when signed by the representatives of the Participants representing a voting majority. Fuels Committee representatives may, by prior arrangement with the chairperson of the Fuels Committee, attend a meeting of the Fuels Committee by conference call or video. A Fuels Committee representative who is unable to attend a meeting of the Fuels Committee may vote in absentia by delivering to the chairperson of the Fuels Committee, at least twenty-four (24) hours prior to the scheduled commencement of the meeting, a written statement, including by e-mail or facsimile, identifying the matter to be voted on and how the representative desires to vote.

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21.0AUDITING COMMITTEE:

21.1The Auditing Committee shall remain in existence during the term of this Agreement. The Auditing Committee shall have no authority to modify any of the provisions of this Agreement.

21.2 The Auditing Committee shall consist of one representative from each Participant. Any of the Participants may designate an alternate or substitute to act as its representative on the Auditing Committee in the absence of the regular representative on the Auditing Committee or to act on specified occasions or with respect to specified matters. Each Participant shall notify the other Participants promptly, in writing, of the designation of its representative and alternate representative on the Auditing Committee and of any subsequent changes in such designation.

21.3The Auditing Committee shall have the following functions and responsibilities under this Agreement:

21.3.1Review accounting, financial and internal control aspects of Operating Work and Capital Improvements, and implementation of procedures established pursuant to Section 20.3.8, and, not less than every two years, audit the records maintained by the Operating Agent in its performance of Operating Work, Capital Improvements and any other records maintained by the Operating Agent in support of its billings to the Participants.

21.3.2Review and approve the format and content of the Operating Agent’s accounting records and reports for Operating Work and Capital Improvements.

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21.3.3Certify to the Participants, for management purposes and for the use of the Participants only, that the Operating Agent’s results of operations and accounting methods and records, including any allocations for Operating Work and Capital Improvements, are in accordance with the Project Agreements and Accounting Practice.

21.3.4Review and make recommendations to the Coordination Committee regarding a Participant’s administrative and general expense allowance and other normal loadings when such Participant acts as construction agent for Capital Improvements.

21.3.5Review and approve the Operating Agent’s cost and expense allocations between (i) electric generation and related functions and (ii) unrelated functions.

21.3.6Advise and make recommendations to the Coordination Committee and Operating Agent on matters involving auditing and financial transactions.

21.3.7Develop procedures for proper accounting and financial liaison between Participants in connection with the Operating Work and Capital Improvements.

21.3.8Perform such functions and responsibilities as may be assigned to it from time to time by the Coordination Committee or as otherwise provided in this Agreement.

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21.4 Any action or determination of the Auditing Committee shall require a vote of the voting Participants in accordance with Section 18.4.1. A Participant’s Auditing Committee representative shall be entitled to vote on all matters except those actions or determinations which relate solely to a Unit or common property in which such Participant does not have a Participation Share except that if a Participant’s right to vote has been suspended pursuant to Section 35.4.1, the requisite majority for actions or determinations specified in Section 18.4.1 shall be adjusted in proportion to the number of Participants whose right to vote has not been suspended. An example of such an adjustment is provided in Exhibit VIII.

21.5The Auditing Committee shall keep written minutes and records of all meetings, and any action or determination by the Auditing Committee shall be reduced to writing and shall become effective when signed by the representatives of the Participants entitled to vote thereon, representing a voting majority of the members of the Auditing Committee. Auditing Committee representatives may, by prior arrangement with the chairperson of the Auditing Committee, attend a meeting of the Auditing Committee by conference call or video conferencing. An Audit Committee representative who is unable to attend a meeting of the Audit Committee may vote in absentia by delivering to the chairperson of the Audit Committee, at least twenty-four (24) hours prior to the scheduled commencement of the meeting, a written statement, including by e-mail or facsimile, identifying the matter to be voted on and how the representative desires to vote.

21.6In the event less than a requisite majority of the Auditing Committee is obtained, the matter shall be referred to the Coordination Committee for decision upon the request of any Participant’s Auditing Committee representative.

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21.7In the event the Auditing Committee fails to reach agreement on a matter which such committee is authorized to determine, approve or otherwise act upon after a reasonable opportunity to do so, then the Operating Agent shall be authorized and obligated to take such reasonable and prudent action, consistent with Prudent Utility Practice, as is necessary to the successful and proper operation and maintenance of the San Juan Project, pending the resolution, by arbitration or otherwise, of any such inability or failure to agree.

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PART V

BUDGETS AND OPERATING EXPENSES

22.0OPERATION AND MAINTENANCE EXPENSES:

22.1The expenses for the operation and maintenance of the San Juan Project in the performance of Operating Work (which, for purposes of this Section 22, and as defined more particularly herein, are referred to as the “O&M Expenses”) shall be apportioned among the Participants, in accordance with the following percentages:

22.1.1For Units 1 and 2 and for all equipment and facilities directly related to Units 1 and 2 only, in accordance with the following percentages:

22.1.1.1PNM - 50 percent

22.1.1.2TEP - 50 percent

22.1.1.3M-S-R - 0 percent

22.1.1.4Farmington - 0 percent

22.1.1.5Tri-State - 0 percent

22.1.1.6LAC - 0 percent

22.1.1.7SCPPA - 0 percent

22.1.1.8Anaheim - 0 percent

22.1.1.9UAMPS - 0 percent

22.1.2For Unit 3 and all equipment and facilities directly related to Unit 3 only, in accordance with the following percentages:

22.1.2.1PNM - 50 percent

22.1.2.2TEP - 0 percent

22.1.2.3M-S-R - 0 percent

22.1.2.4Farmington - 0 percent

22.1.2.5 Tri-State - 8.2 percent

22.1.2.6LAC - 0 percent

22.1.2.7SCPPA - 41.8 percent

22.1.2.8Anaheim - 0 percent

22.1.2.9UAMPS - 0 percent

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22.1.3For Unit 4 and for all equipment and facilities directly related to Unit 4 only, in accordance with the following percentages:

22.1.3.1PNM - 38.457 percent

22.1.3.2TEP - 0 percent

22.1.3.3M-S-R - 28.8 percent

22.1.3.4Farmington - 8.475 percent

22.1.3.5 Tri-State - 0 percent

22.1.3.6LAC - 7.20 percent

22.1.3.7SCPPA - 0 percent

22.1.3.8Anaheim - 10.04 percent

22.1.3.9UAMPS - 7.028 percent

22.1.4For equipment and facilities common to Units 1 and 2 only, in accordance with the following percentages:

22.1.4.1PNM - 50 percent

22.1.4.2TEP - 50 percent

22.1.4.3M-S-R - 0 percent

22.1.4.4Farmington - 0 percent

22.1.4.5 Tri-State - 0 percent

22.1.4.6LAC - 0 percent

22.1.4.7SCPPA - 0 percent

22.1.4.8Anaheim - 0 percent

22.1.4.9UAMPS - 0 percent

22.1.5For equipment and facilities common to Units 3 and 4 only, in accordance with the following percentages:

22.1.5.1PNM - 44.119 percent

22.1.5.2TEP - 0 percent

22.1.5.3M-S-R - 14.4 percent

22.1.5.4Farmington - 4.249 percent

22.1.5.5 Tri-State - 4.1 percent

22.1.5.6LAC - 3.612 percent

22.1.5.7SCPPA - 20.9 percent

22.1.5.8Anaheim - 5.07 percent

22.1.5.9UAMPS - 3.55 percent

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22.1.6For the Switchyard Facilities except as otherwise provided in Section 15, in accordance with the following percentages:

22.1.6.1PNM - 65 percent

22.1.6.2TEP - 35 percent

22.1.6.3M-S-R - 0 percent

22.1.6.4Farmington - 0 percent

22.1.6.5 Tri-State - 0 percent

22.1.6.6LAC - 0 percent

22.1.6.7SCPPA - 0 percent

22.1.6.8Anaheim - 0 percent

22.1.6.9UAMPS - 0 percent

22.1.7Except as provided in Exhibit V(g), attached hereto and incorporated herein, for equipment and facilities common to all of the Units, and all San Juan Project expenses not identifiable by Unit and not otherwise listed above, in accordance with the following percentages:

22.1.7.1PNM - 46.297 percent

22.1.7.2TEP - 19.8 percent

22.1.7.3M-S-R - 8.7 percent

22.1.7.4Farmington - 2.559 percent

22.1.7.5 Tri-State - 2.49 percent

22.1.7.6LAC - 2.175 percent

22.1.7.7SCPPA - 12.71 percent

22.1.7.8Anaheim - 3.10 percent

22.1.7.9UAMPS - 2.169 percent

22.1.8In the event of a permanent shutdown of either of Unit 1 or Unit 2, the expenses incurred in connection with the shutdown (which may include removal, salvage, cleanup and protection service) shall be allocated as set forth in Section 22.1.1. In the event of a permanent shutdown of Unit 3, said expenses shall be allocated as set forth in Section 22.1.2. In the event of a permanent shutdown of Unit 4, said expenses shall be allocated as set forth in Section 22.1.3. Expenses which are attributable to equipment and facilities common to more than one Unit shall be apportioned in accordance with Section 22.1, as applicable.

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22.1.9Exhibit V, attached hereto and incorporated herein, is a partial list of equipment and facilities of the San Juan Project for use by the Engineering and Operating Committee as a guideline in determining the allocation of operation and maintenance costs among the Participants.

22.1.10 In areas where the allocation of costs of operation and maintenance of equipment and facilities among the Participants is not clearly defined by Sections 22.1.1 to 22.1.8, the Engineering and Operating Committee shall make a determination of such allocation of costs.

22.1.11 The following shall apply in the event of a declaration of default against a Participant and a suspension of that Participant’s right to receive all or any part of its proportionate share of the Net Effective Generating Capacity, as provided for in Section 35.4.1: those non-defaulting Participant(s) having a Participation Share in each affected Unit, who are entitled to schedule and receive for their accounts proportionate shares of the Net Effective Generating Capacity of the defaulting Participant, shall bear proportionate shares of the defaulting Participant’s responsibility for expenses of the operation and maintenance of the San Juan Project, as provided in Section 35.5.

22.2O&M Expenses chargeable to the following FERC Accounts shall be apportioned among the Participants in accordance with Sections 22.1.1, 22.1.2, 22.1.3, 22.1.4, 22.1.5 and 22.1.7, as applicable:

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22.2.1Power Production/Steam Power Generation:FERC Accounts 500, 502, 505, 506, 507, 509 and 510 through 514 (charged by on-site San Juan Project employees and operations-related departments located off-site); provided, however, that limestone costs (chemicals) chargeable to FERC Account 502 shall be apportioned among the Participants in accordance with Section 23.5.

22.2.2Administrative and General Expenses directly chargeable to FERC Accounts 920, 921, 923, 926, 930.2, 931 and 935, by on-site San Juan Project employees and by A&G related departments located off-site as set forth in Exhibit VI, Attachment A, which have not been included as a part of the A&G Ratio or charged to FERC Account 935, in accordance with Section 22.4. Such direct A&G charges must be supported by the Operating Agent and are subject to audit and approval by the Auditing Committee. If the Auditing Committee is unable to agree on the appropriateness of direct A&G charges, the Auditing Committee shall submit the entire matter to the Coordination Committee.

22.2.3O&M Expenses chargeable to FERC Account 501 shall be apportioned among the Participants in accordance with Section 23.

22.2.4The cost of the property insurance for the San Juan Project chargeable to FERC Account 924 and any uninsured loss or expense thereunder and the cost of general liability or workers’ compensation insurance for the San Juan Project chargeable to FERC Account 925 shall be apportioned among the Participants according to Section 22.1.

22.2.5 Costs or revenues chargeable to the following FERC Operating and Non-Operating Accounts: 411.8, 411.9, 412, 421 and 426.

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22.3Power Production Expense chargeable to FERC Account 500 (for employees of PNM’s fuels management department), Non San Juan Project Specific, shall be allocated among all of PNM’s fossil-fueled power plants, including the San Juan Project, based on the percentage of labor charged to each fossil-fueled power plant as a percentage of labor charged to all of PNM’s fossil-fueled power plants.

22.4The O&M Expenses for the Switchyard Facilities chargeable to FERC Accounts 560 through 573 and FERC Account 935 shall be apportioned among the Participants in accordance with Section 22.1.6.

22.5The O&M Expenses for the portion of system control and load dispatching expenses (allocated between PNM and the San Juan Project based on the number of megawatts of San Juan Project capacity as a percentage of PNM’s total generating capacity) chargeable to FERC Accounts 556, 560 and 561 shall be apportioned among the Participants in accordance with Section 22.1.7.

22.6Payroll loads for administrative and general expenses, payroll taxes, injuries and damages and pension and benefits, shall be added to the monthly billings in proportion to the dollars of direct labor billed and apportioned among the Participants in accordance with Sections 22 and 23. The current methodologies for calculating the A&G Ratio, Payroll Tax Ratio, Injuries and Damages Ratio and Pension and Benefits Ratio are set forth in Exhibit VI (Attachments A, B, C and D thereto), attached hereto and incorporated herein.

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22.6.1If any Participant believes that the method used in determining A&G Ratio, Payroll Tax Ratio, Injuries and Damages Ratio and Pension and Benefits Ratio, in accordance with Exhibit VI (Attachments A, B, C and D thereto), results in an unreasonable burden on such Participant(s), such Participant(s) may request that said method used in determining said ratios be submitted to the Auditing Committee for review. After any such request, the Auditing Committee shall review said method and shall endeavor to agree upon whether or not said unreasonable burden does actually exist. If, after such review, the Auditing Committee determines that the application of said method does result in an unreasonable burden on the Participant, the Auditing Committee shall determine and recommend a modified method to the Coordination Committee to eliminate such unreasonable burden. If, after such review, the Auditing Committee is unable to agree upon whether or not such unreasonable burden does exist or is unable to agree on a modified method for eliminating said unreasonable burden, the Auditing Committee shall submit the entire matter to the Coordination Committee.

22.6.2The Coordination Committee shall review the recommendation of the Auditing Committee pursuant to Section 22.6.1. If, as a result of such review, the Coordination Committee agrees that such unreasonable burden does exist and that a modified method eliminates such unreasonable burden, the Coordination Committee shall adopt said modified method.

22.6.3If the Auditing Committee has not submitted a recommended modified method and the Coordination Committee agrees that such unreasonable burden does exist, the Coordination Committee shall endeavor to agree on a modified method. If, after such review, the Coordination Committee is unable to agree that such unreasonable burden does exist or on a modified method which will eliminate such unreasonable burden, upon request of a Participant, either matter may be submitted to arbitration pursuant to Section 37.

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22.6.4Any modified method adopted by the Coordination Committee or determined through arbitration shall be retroactive for the length of the period of inequity up to a maximum period of three (3) years and shall become effective on the first day following such date of adoption.

22.7As soon as possible after the end of each calendar year, the Operating Agent shall calculate the actual ratios for: A&G, payroll tax, injuries and damages, and pension and benefits for such year in accordance with the methodologies described in Exhibit VI (Attachments A, B, C and D thereto). To the extent such expenses are more or less than those already paid by the Participants during said year, the Operating Agent shall bill or credit the Participants for the amount of such difference.

22.8At the start of each calendar year, the Operating Agent shall calculate new ratios for: A&G, payroll tax, injuries and damages and pension and benefits. Such ratios shall be calculated in accordance with the methodologies described in Exhibit VI (Attachments A, B, C and D thereto). Such ratios may be adjusted to more nearly reflect the anticipated expenses of the current year because of tax legislation, labor contract negotiations or other factors not reflected in the prior year’s costs.

22.9The Operating Agent shall bill to the requesting Participant(s) the costs and expenses, including A&G expenses, incurred by the Operating Agent (including, but not limited to, fees of outside legal counsel or consultants, time of in-house legal counsel and other employees and agents of the Operating Agent) in performing tasks requested by

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a Participant in relation to (i) the offering or sale of bonds or other type of security by a Participant in connection with the acquisition or ownership of an interest in the San Juan Project; and (ii) the attempted or contemplated sale by a Participant of any portion of its ownership interest in the San Juan Project. The Operating Agent shall establish and maintain appropriate accounting procedures to identify such costs and expenses incurred by the Operating Agent.

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23.0FUEL COSTS:

23.1The quantity of coal delivered to the San Juan Project shall be determined by the belt scales, in accordance with the Underground Coal Sales Agreement.

23.2The Operating Agent shall maintain the Project Coal Inventory wherein ownership shall be apportioned among the Participants based on Common Participation Share. Coal inventory shall be accounted for in FERC Account 151.

23.3All Participants acknowledge and recognize the terms and conditions of the Underground Coal Sales Agreement which was entered into by PNM and TEP on behalf of the Participants. Exhibit VII, attached hereto and incorporated herein, contains example “Interim Invoices”, “UG-CSA Invoices”, and “UPS Invoices” prepared and defined pursuant to Section 8 of the Underground Coal Sales Agreement.

23.4Monthly costs of the Project Coal Inventory and fuel expense shall be apportioned among and paid for by the Participants on the following basis:

23.4.1UG-CSA Invoicing Allocations

In the event that UG-CSA Invoices are rendered and payable pursuant to Section 8.7 (A) of the Underground Coal Sales Agreement, amounts due thereunder shall be allocated and paid for by the Participants as Fixed Fuel Expense and Variable Fuel Expense as described in: Exhibit IX, Fixed Fuel Expense; and Exhibit X, Variable Fuel Expense and as provided below:

23.4.1.1Costs that are classified as Fixed Fuel Expense shall be charged to FERC Account 501, or to such FERC Account number as may be applicable in the future if fuel deliveries terminate, and shall be apportioned among and paid for by the Participants in accordance with Common Participation Share.

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23.4.1.2Costs that are classified as Variable Fuel Expense shall be charged to FERC Account 151 and such costs shall be apportioned among and paid for by the Participants on the basis of Common Participation Share. Monthly cost for coal withdrawn from Project Coal Inventory (equivalent to total monthly Participant Coal Consumption) shall be credited to FERC Account 151 and charged to FERC Account 501 on an average price basis as determined by dividing the total number of tons of coal in Project Coal Inventory at the beginning of the month, plus the coal delivered during the month, into the total recorded cost in FERC Account 151 and multiplying the cost per ton so derived by the number of tons withdrawn. The cost for coal withdrawn charged to FERC Account 501 shall be apportioned among and paid for by the Participants on the basis of the percentage that each Participant’s monthly Participant Coal Consumption bears to the total monthly Participant Coal Consumption of all Units. The cost for coal withdrawn thusly credited to FERC Account 151 shall be apportioned among the Participants on the basis of Common Participation Share.

23.4.1.3Any other Total Monthly Coal Cost not currently classified in Exhibits IX or X as Fixed Fuel Expense or Variable Fuel Expense shall be deemed to be Fixed Expense until reclassified by the Coordination Committee.

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23.4.2Interim Invoicing Allocations

In the event that Interim Invoices are rendered and payable pursuant to Section 8.7 (B) of the Underground Coal Sales Agreement, such costs shall be allocated and invoiced to the Participants as described below.

23.4.2.1The Base Price (“Base Price”) band shall be based on the Minimum Annual Tons. The annual allocation of the coal tonnage in the Base Price band shall be made among the Participants on the basis of Common Participation Share. The monthly allocation of the coal tonnage in the Base Price band shall be made among the Participants on the basis of each Participant’s share of Monthly Minimum Tons. The cost of the monthly Base Price band will be allocated among and paid for by the Participants by multiplying each Participant’s share of Monthly Minimum Tons by the Base Price.

23.4.2.2The Incremental Price (“Incremental Price”) band(s) shall be based on (an) annualized band(s) of tons of coal delivered in excess of Minimum Annual Tons. The cost of the monthly Incremental Price band(s) will be allocated among and paid for by the Participants by multiplying each Participant’s consumption of Incremental Price band coal(s) by the Incremental Price for such band(s). Participants shall only be eligible for allocation of Incremental Price band coal pricing if their monthly Participant Coal Consumption exceeds their share of Monthly Minimum Tons.

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23.4.2.3At the end of each year, the Operating Agent shall reconcile the sum of each Participant’s monthly Interim Invoice-related payments to a properly allocable share of Base Price band tons, Incremental Price band or bands tons, and cost associated with any change in Project Coal Inventory and invoice or refund any such reconciliation amounts to each Participant. This reconciliation will be exclusive of any year-end true up required pursuant to Section 23.4.2.6.

23.4.2.4In the year-end reconciliation process of Section 23.4.2.3, any amount credited by SJCC for tons invoiced but not delivered shall be credited to FERC Account 501 and apportioned to the Participants on the basis of the percentage that each Participant’s annual Incremental Price Band(s) consumption bears to the total annual Incremental Price Band(s) consumption for all Units. Any net consumption of Project Coal Inventory tons shall be charged to FERC Account 501 and apportioned among and paid for by the Participants on the basis of the percentage that each Participant’s annual Incremental Price Band(s) consumption bears to the total annual Incremental Price Band(s) consumption for all Units. The price for such tons shall be determined by dividing the total recorded cost in FERC Account 151 by the total number of tons of coal in Project Coal Inventory, both as recorded on January 1 of said year. The total amount of any such payment for consumed Project Coal Inventory tons shall subsequently be credited to FERC Account 151 and apportioned to the Participants based on Common Participation Share.

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In the year-end reconciliation process of Section 23.4.2.3, the costs of any net addition to Project Coal Inventory tons, as invoiced by SJCC, shall be charged to FERC Account 151 and apportioned to and paid for by the Participants based on Common Participation Share.

23.4.2.5If, at the end of any year, the Operating Agent has collected amounts in excess of those due SJCC pursuant to Section 8.7(B) of the Underground Coal Sales Agreement, but not including any year-end true up required pursuant to Section 23.4.2.6, such over-collection shall be refunded to the Participants. The refund to each Participant shall be an amount equal to the total amount of the over-collection multiplied by the tons each Participant’s Coal Consumption was less than its total annual Monthly Minimum Tons divided by the total amount by which all such Participants’ Coal Consumption was less than their shares of Minimum Annual Tons.

23.4.2.6The Interim Invoices shall be annually reconciled to invoices prepared pursuant to Section 8.7(A) of the Underground Coal Sales Agreement. Any adjustment required by this reconciliation, in accordance with Section 8.7(B) of the Underground Coal Sales Agreement, will be passed through to the Participants as correcting invoices and will be apportioned among and paid for by, or credited to, the Participants on the basis of Common Participation Share.

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23.4.2.7Monthly UPS payments shall be apportioned among and paid for by the Participants on the basis of Common Participation Share

23.4.2.8Any other component of Total Monthly Coal Cost which is not classified as Base Price or Incremental Price shall be apportioned among and paid for by the Participants on the basis of Common Participation Share unless otherwise annually approved by the Fuels Committee.

23.4.2.9If during any year, payable Interim Invoices cease to be rendered by SJCC pursuant to Section 8.7(B) of the Underground Coal Sales Agreement, the Participants acknowledge and recognize that Interim Invoicing cannot be in effect for a partial year, and that all allocations of Total Monthly Coal Costs for the year shall then be made pursuant to Section 23.4.1. Amounts previously allocated to the Participants pursuant to Section 23.4.2 in the effected year shall be reallocated pursuant to the provisions of Section 23.4.1.

23.4.2.10The Fuels Committee may terminate allocation of costs to the Participants pursuant to Section 23.4.2 despite the continued receipt of payable Interim Invoices from SJCC, if the Fuels Committee determines that coal cost allocation pursuant to Section 23.4.1 better serves

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the interests of the San Juan Project. Such termination may only be made upon action of the Fuels Committee pursuant to Section 20.5. In the event of such termination, costs shall continue to be apportioned to and paid for by the Participants pursuant to Section 23.4.2. However, for information purposes, the Operating Agent shall also provide cost allocations to the Participants pursuant to Section 23.4.1. At the end of such year, the amounts paid by the Participants shall be reconciled to those amounts allocated pursuant to Section 23.4.1 for each month of the affected year (Section 23.4.1 allocations being determinative) and the Operating Agent shall invoice or refund any such reconciliation amounts to each Participant.

23.5Limestone costs (chemicals) chargeable to FERC Account 502 shall be apportioned among and paid for by the Participants on the basis of the percentage that each Participant’s monthly Participant Coal Consumption bears to the total monthly Participant Coal Consumption of all Units.

23.6All other fuel-related expenses which are chargeable to FERC Account 501 shall be apportioned among and paid for by the Participants on the following basis:

23.6.1Variable fuel-related expenses (including, but not limited to ash and gypsum disposal) on the basis of the percentage that each Participant’s monthly Participant Coal Consumption bears to the total monthly Participant Coal Consumption of all Units.

23.6.2Fixed fuel-related expenses (including, but not limited to fuel handling) on the basis of Common Participation Share.

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23.6.3Fuel oil purchased for use at the San Juan Project is first delivered into one of two storage tanks. Tank 1 and 2 storage tank feeds Units 1 and 2 and Tank 3 and 4 storage tank feeds Units 3 and 4. When oil is withdrawn from a storage tank for consumption, it is metered by Unit. Costs for fuel oil usage shall be separately accounted for by these two storage tanks as follows:

23.6.3.1Costs for fuel oil purchases to Tank 1 and 2 shall be charged to FERC Account 151 and such costs shall be apportioned among and paid for by the Units 1 and 2 Participants on the basis of Section 6.2.4. Monthly cost for fuel oil withdrawn from Tank 1 and 2 shall be credited to FERC Account 151 and charged to FERC Account 501 on an average price basis as determined by dividing the total number of gallons of fuel oil in Tank 1 and 2 at the beginning of the month, plus the fuel oil delivered during the month, into the total recorded cost in FERC Account 151 and multiplying the cost per gallon so derived by the number of gallons withdrawn from Tank 1 and 2. The cost for fuel oil withdrawn from Tank 1 and 2 charged to FERC Account 501 shall be apportioned among and paid for by the Units 1 and 2 Participants first on the basis of the individual Unit metered consumption and then on the basis of Section 6.2.1. The cost for fuel oil withdrawn from Tank 1 and 2 thusly credited to FERC Account 151 shall be apportioned among the Units 1 and 2 Participants on the basis of Section 6.2.4.

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23.6.3.2Costs for fuel oil purchases to Tank 3 and 4 shall be charged to FERC Account 151 and such costs shall be apportioned among and paid for by the Units 3 and 4 Participants on the basis of Section 6.2.5. Monthly cost for fuel oil withdrawn from Tank 3 and 4 shall be credited to FERC Account 151 and charged to FERC Account 501 on an average price basis as determined by dividing the total number of gallons of fuel oil in Tank 3 and 4 at the beginning of the month, plus the fuel oil delivered during the month, into the total recorded cost in FERC Account 151 and multiplying the cost per gallon so derived by the number of gallons withdrawn from Tank 3 and 4. The cost for fuel oil withdrawn from Tank 3 and 4 charged to FERC Account 501 shall be apportioned among and paid for by the Units 3 and 4 Participants first on the basis of the individual Unit metered consumption and then on the basis of Section 6.2.2 or Section 6.2.3, as applicable. The cost for fuel oil withdrawn from Tank 3 and 4 thusly credited to FERC Account 151 shall be apportioned among the Units 3 and 4 Participants on the basis of Section 6.2.5.

23.7The Operating Agent shall provide the Participants a monthly written report on the following items related to coal deliveries at the San Juan Project:

23.7.1 Minimum Annual Tons for the year.

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23.7.2 Minimum Annual Tons allocated among the Participants.

23.7.3Total actual coal deliveries by SJCC to the San Juan Project for each month and for the year to date.

23.7.4Total actual coal deliveries to the San Juan Project for each month and for the year to date, allocated to the Participants.

23.7.5Total cost and tonnage of inventory allocated to the Participants.

23.7.6Fixed Fuel Expense and Variable Fuel Expense totals as allocated to each Participant for each month and for the year to date if UG-CSA Invoicing is, or will be, required for said year pursuant to Section 23.4.1.

23.8The Operating Agent shall work diligently with SJCC under the terms of the Underground Coal Sales Agreement to manage Project Coal Inventory so as to maintain the Emergency Coal Storage Pile at target levels pursuant to Section 20.3.6 and to maintain appropriate working levels of Project Coal Inventory to facilitate San Juan Project Operations.

23.9In the event that SJCC defaults in its obligations under the Underground Coal Sales Agreement or otherwise fails to maintain deliveries of coal, the Operating Agent may assume or make such arrangements for the assumption of such of SJCC’s operations as permitted by the Underground Coal Sales Agreement or may procure, subject to the Underground Coal Sales Agreement, an alternate coal supply. Costs associated with such assumed coal operations or the procurement and supply of alternate coal shall be deemed a part of Total Monthly Coal Cost and, with the costs and expenses of fuel and emission residuals (gypsum) and ash disposal, shall be apportioned between and paid for by the Participants in accordance with: (i) Section 23.4.1 with regard to coal costs; and (ii) Section 23.6.1 with regard to fuel-related costs.

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23.10The monthly costs of fuel allocated among the Participants in accordance with this Section 23 shall be estimated by the Operating Agent as soon as practicable after the end of each month and a preliminary bill shall be presented and paid in the manner set forth in Section 30.3.3. Adjustments and corrections to the estimated preliminary bill shall be made in the next succeeding month or on the earliest possible billing thereafter.

23.11In the event of a catastrophic occurrence which results in a sustained outage of a Unit and a determination that an “Uncontrollable Force” exists under the Underground Coal Sales Agreement, then in such event, FERC Account 151 will be allocated to the operable and non-operable Units. The portion of FERC Account 151 allocated to the non-operable Unit(s) shall remain frozen until such time as such Unit(s) is restored to operable condition. New costs of coal chargeable to FERC Account 151 will be apportioned among the Participants on the basis of the Participants’ Participation Shares in the generating capacity of the operable Units. At such time as a damaged Unit is restored to operable condition, the frozen portion of Account 151 will be merged into the operable unit(s) portion of Account 151 and to the extent that a Participant is adversely impacted by an incremental increase in the average unit cost of coal an allocation of such incremental cost will be made and the net difference paid by the Participant having a credit balance.

23.12The accounting practices and billing and accounting principles as stated in this Section 23 are applicable at the present time. If, however, at a later time these practices or principles are proven to be inadequate or other practices or principles later prove to be more equitable in the opinion of the Auditing Committee, the Coordination Committee, upon the recommendation of the Auditing Committee, may authorize changes and revisions to such practices and principles.

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23.13Any other fuel-related costs not currently classified in this Section 23 shall be apportioned among and paid for by the Participants on the basis of the percentage that each Participant’s monthly Participant Coal Consumption bears to the total monthly Participant Coal Consumption of all Units until classified by the Coordination Committee.

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24.0ANNUAL BUDGETS:

24.1Not less than ninety (90) days prior to the beginning of each calendar year, the Operating Agent shall prepare and submit to the Engineering and Operating Committee for its review and approval the proposed capital budget, manpower budget and a budget for the performance of Operating Work for such calendar year.

24.2The Engineering and Operating Committee shall approve the budgets described in Section 24.1 in final form not less than thirty (30) days prior to their effective date. In the event that any such budget is not so approved, the Operating Agent will nevertheless continue to perform Operating Work in a manner consistent with Prudent Utility Practice until such time as a budget has been approved.

24.3Any information required from the Participants by the Operating Agent in preparing such proposed budgets will be supplied by the Participants, if possible, within thirty (30) days following a request by the Operating Agent.

24.4The Engineering and Operating Committee may at any time during the year approve revisions to the approved capital expenditures budget, manpower budget and a budget for the performance of Operating Work.

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25.0PAYMENT OF TAXES:

25.1The Participants shall use their best efforts to have any taxing authority imposing any taxes or assessments on the San Juan Project, assess and levy such taxes or assessments directly against each Participant in accordance with its respective Participation Share in the property taxed.

25.2All taxes or assessments levied against each Participant’s ownership interest in the San Juan Project, excepting those taxes or assessments levied against an individual Participant on behalf of other Participants, shall be the sole responsibility of the Participant upon whom said taxes and assessments are levied.

25.3If any property taxes and other taxes and assessments are levied and assessed in a manner other than specified in Section 25.1, it shall be the responsibility of the Coordination Committee to establish equitable standard practices and procedures for the apportionment among the Participants of such taxes and assessments and the payment thereof.

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26.0MATERIALS AND SUPPLIES:

26.1The Operating Agent from time to time may increase or reduce the inventory of Materials and Supplies by changing the maximum or the minimum quantities to be maintained in inventory in accordance with the procedures established by the Engineering and Operating Committee.

26.2The Operating Agent shall prepare a list of the items for inclusion in Materials and Supplies for the operation and maintenance of each Unit. The list shall include the estimated cost of each individual item of such Materials and Supplies and specify the maximum and minimum quantity of each such individual item to be maintained in inventory. The list shall be submitted to the Engineering and Operating Committee by the Operating Agent for review and approval.

26.3The Operating Agent shall purchase and take control of Materials and Supplies for inventory, so that the total inventory of Materials and Supplies on hand remains in accordance with the policies established by the Engineering and Operating Committee.

26.4Materials and Supplies withdrawn from inventory and used in the operation and maintenance of the San Juan Project shall be accounted for as a component of operation and maintenance expense and allocated among the Participants in accordance with Section 22.

26.5Materials and Supplies withdrawn from inventory and used in connection with Capital Improvements shall be accounted for as a capital expenditure and allocated among the Participants in accordance with Section 7.

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26.6Materials and Supplies removed from service shall be returned to inventory if reusable, or if junk or obsolete, shall be disposed of by the Operating Agent under the best available terms. The proceeds, if any, received shall be credited or distributed to the Participants in the same proportion as their Participation Shares therein.

26.7A separate Materials and Supplies account and undistributed stores expense account will be established by the Operating Agent in accordance with FERC Accounts. Such charges and credits so allocated to Materials and Supplies shall be allocated to the Participants as a component of operation and maintenance expense in accordance with Section 22, or as a Capital Improvement in accordance with Section 7, as the case may be.

26.8The inventory value of any item withdrawn from or returned to Materials and Supplies shall be the average cost of like items in inventory.

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27.0EMERGENCY SPARE PARTS:

27.1The Operating Agent shall prepare a list of the Emergency Spare Parts for each Unit and common facilities. Such list shall include the estimated costs for each individual item of such Emergency Spare Parts and shall specify the quantity of each such individual item to be maintained in inventory. Such list shall be submitted to the Engineering and Operating Committee by the Operating Agent for review and approval.

27.2The Operating Agent shall purchase Emergency Spare Parts from time to time as replacements for those withdrawn from inventory in accordance with the policies established by the Engineering and Operating Committee.

27.3Emergency Spare Parts shall be owned by and the costs thereof shall be allocated between the Participants in accordance with their respective Participation Shares.

27.4The Operating Agent shall notify the Participants promptly after Emergency Spare Parts are withdrawn from inventory and shall also notify the Participants of the value of such parts so withdrawn and of the accounting treatment with respect thereto.

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PART VI

OPERATING AGENT

28.0OPERATION AND MAINTENANCE:

28.1PNM is the Operating Agent, unless replaced in accordance with Section 33.

28.2All Participants hereby appoint PNM as their agent, and PNM agrees to undertake, as the agent of the Participants and as principal on its own behalf, the responsibility for the performance of Operating Work in accordance with this Agreement.

28.3Subject to the provisions, conditions, limitations and restrictions of this Agreement, the Operating Agent shall:

28.3.1Perform the Operating Work in accordance with the Project Agreements and Prudent Utility Practice.

28.3.2Contract for, furnish or obtain the services and studies necessary for performance of Operating Work.

28.3.3Arrange for the placement and maintenance of Operating Insurance.

28.3.4Execute all contracts in the name of the Operating Agent, acting as principal on its own behalf and as agent for the Participants, in connection with the performance of Operating Work.

28.3.5Furnish and train the necessary personnel for performance of Operating Work.

28.3.6Have the coal replaced which has been removed from the Emergency Coal Storage Pile at the earliest practical time following resumption of normal coal deliveries.

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28.3.7Enforce and comply with all contracts entered into for the performance of Operating Work.

28.3.8Comply with any and all laws and regulations applicable to the performance of Operating Work.

28.3.9Maintain the Operating Account and expend the Operating Funds only in accordance with this Agreement.

28.3.10 Keep and maintain records of monies expended and received, obligations incurred, credits accrued and contracts entered into in the performance of this Agreement, and make such records available for inspection by the Participants at reasonable times and places.

28.3.11 Not suffer any liens to remain in effect unsatisfied against the San Juan Project (other than the liens permitted under Section 10.1, for taxes or assessments not yet delinquent, for labor and material not yet delinquent or undetermined charges or liens incidental to the performance of Operating Work); provided, that the Operating Agent shall not be required to pay or discharge any such lien as long as a proceeding shall be pending in which the lawfulness or validity of such lien shall be contested in good faith and which shall operate during the pendency thereof to prevent the collection or enforcement of such lien so contested.

28.3.12 Recommend minimum notification times and lead times for changing scheduled Energy required for the Participants to the Engineering and Operating Committee for its approval.

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28.3.13 Act as operating representative or agent in connection with the administration and enforcement of the Underground Coal Sales Agreement.

28.3.14 Recommend programs to the Engineering and Operating Committee to make environmental studies and, upon approval of the Engineering and Operating Committee, supervise the performance of such programs.

28.3.15 Provide the Engineering and Operating Committee with all written statistical and administrative reports, written budgets, information and other records relating to Operating Work which may be necessary to permit such committee to perform its responsibilities under this Agreement.

28.3.16 Provide the Fuels Committee with all written reports, written budgets, information and other records relating to Operating Work which may be necessary to permit such committee to perform its responsibilities under this Agreement.

28.3.17 Provide the Auditing Committee with all accounting records, information, reports and other records relating to Operating Work, which may be necessary to permit such committee to perform its responsibilities under this Agreement.

28.3.18 Perform Operating Work so as to comply with the Water Contract(s) and make such tests and measurements and keep such records as are required by applicable agreements, regulations and statutes.

28.3.19 Keep the Participants fully and promptly advised of material changes in conditions or other material developments affecting the performance of Operating Work and furnish the Participants with copies of any notices given or received pursuant to the Project Agreements.

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28.3.20 Present claims to any insurer for losses and damages covered by valid and collectible Operating Insurance procured by the Operating Agent directly from the insurer. Investigate, adjust, settle, decline and defend claims against the Participants arising out of the performance of Operating Work when said claims or portions thereof are not covered by valid and collectible Operating Insurance; provided that the Operating Agent shall obtain the agreement of the Participants, acting through the Coordination Committee, prior to disposing of any claims or combination of claims arising out of the same occurrence which exceeds one hundred thousand dollars ($100,000).

28.3.21 Assist, as requested, other Participants and their insurers in the investigation, adjustment and settlement of any loss or claim arising out of Operating Work for which payment may be made on account of valid and collectible additional insurance applicable thereto procured by any such Participant; provided, that the Operating Agent may agree (by separate agreement) that a Participant procuring any policy or policies of additional insurance shall have the authority and the responsibility to (i) present, investigate, adjust, settle, decline and defend claims or potential claims covered by said policies in favor of the Participants and against any one or more of said insurers; and (ii) present, investigate, adjust, settle, decline and defend claims against the Participants arising out of the performance of Operating Work when said claims or portions thereof are not covered by said policies; and provided further, that such Participant shall obtain the agreement of the Participants, acting through the Coordination Committee, prior to the settlement of any claim or combination of claims arising out of the same occurrence which exceeds one hundred thousand dollars ($100,000).

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28.3.22 Notwithstanding anything in Section 28.3.20 and 28.3.21 to the contrary, any Participant may at any time, at its own expense, employ its own counsel to assist in investigating, adjusting, settling, declining and defending claims of the types referred to in Sections 28.3.20 and 28.3.21 and the Operating Agent and its employees and counsel shall cooperate fully with such counsel and permit such counsel to participate fully in all of the foregoing activities.

28.3.23 Keep the Participants fully and promptly informed of any known default under the Project Agreements.

28.3.24 Determine switching and clearance procedures to be followed by the Participants at the San Juan Project.

28.3.25 Determine Available Operating Capacity from time to time and make recommendations to the Engineering and Operating Committee regarding items referenced in Section 19.3.1.9.

28.3.26 Upon the request of a Participant, provide such Participant, in reasonable quantity without direct charge therefor, a copy or copies of any report, record, list, budget, manual, accounting or billing summary, classification of accounts, or other documents or revisions of any of the foregoing items, all as prepared in accordance with this Agreement.

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28.3.27 In the event of the failure of the Participants which are signatories to the Underground Coal Sales Agreement then in effect to reach agreement on a matter described in Sections 18.7 and 20.5.3, maintain a supply of coal to the San Juan Project, consistent with Prudent Utility Practice.

28.3.28Manage the activities of the “designated representative” pursuant to the DR Agreement.

28.3.29Perform all of the duties and obligations set out in this Agreement as duties and obligations of the Operating Agent.

28.4The Participants shall lend and be properly reimbursed for all necessary and available assistance as may be requested by the Operating Agent in the performance of Operating Work.

28.5The Operating Agent shall be the agent of the Participants and shall exercise only such authority as is conferred upon it by this Agreement. The Operating Agent shall not receive any fee or profit hereunder, unless otherwise agreed unanimously by the Participants.

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29.0OPERATING EMERGENCY:

29.1In the event of an Operating Emergency, the Operating Agent shall take any and all steps reasonably necessary and required to terminate the Operating Emergency, subject to the provisions of this Section 29.

29.2As soon as practicable after the commencement of an Operating Emergency, the Operating Agent shall advise the Participants of the occurrence of the Operating Emergency, its nature and the steps taken or to be taken to terminate the Operating Emergency, including a preliminary estimate of the expenditures required to terminate the Operating Emergency.

29.3In the event that the estimated cost to cure an Operating Emergency with respect to any Unit or to any equipment and facilities common to any of the Units does not exceed two hundred and fifty thousand dollars ($250,000), the Operating Agent shall have the authority to expend, in its discretion, no more than two hundred and fifty thousand dollars ($250,000) to terminate such Operating Emergency.

29.4In the event the Operating Agent determines that the estimated amount required to terminate the Operating Emergency exceeds the amount which it is authorized to expend, the Operating Agent shall immediately notify the affected Participants following such determination. The Operating Agent shall provide the following information:

29.4.1 The estimated date when the Operating Emergency can be terminated.

29.4.2The person or persons who would perform the work and furnish the materials required to terminate the Operating Emergency.

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29.4.3The estimated amount of overtime, if any, which would be necessary in order to expedite the termination of the Operating Emergency.

29.4.4The costs that are proposed to be capitalized, and salvage realized.

29.4.5The costs that are proposed to be charged as maintenance expense.

29.4.6The proposed administrative and general expense allowance applicable to such repair or reconstruction.

29.4.7Such other information as may be necessary and required by the Engineering and Operating Committee to determine the manner in which the Operating Emergency is to be terminated.

29.5The Engineering and Operating Committee shall review and approve the proposed repair or reconstruction, including the estimated cost thereof or shall agree upon an alternative.

29.6Costs incurred in terminating an Operating Emergency may be billed to the Participants by the Operating Agent on the basis of its estimate of such costs with adjustment to be made in accordance with Section 29.8 when final cost determination has been made.

29.7Following the termination of the Operating Emergency, the Operating Agent shall submit to the Participants a report containing a summary of the costs incurred and expenditures made in connection with the repair or reconstruction and such other information as may be required by the Engineering and Operating Committee.

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29.8The Operating Agent shall allocate to the Participants the costs incurred or expenditures made in such repair or reconstruction, as follows: (i) costs charged as maintenance expense, in accordance with Section 22; and (ii) any other such repair or reconstruction costs, in accordance with Section 7.

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30.0PAYMENT OF EXPENSES BY PARTICIPANTS:

30.1All amounts required to be advanced by the Participants in accordance with this Agreement shall be made payable to the Operating Account established by the Operating Agent. The Operating Funds shall be owned by the Participants in proportion to their respective balances therein at any given time, and the Operating Agent in its capacity as such shall not have any right or title therein except to maintain custody of and to disburse the Operating Funds as a conduit between the Participants and those to whom such disbursements shall be made.

30.2The Engineering and Operating Committee shall establish a minimum amount for the Operating Funds which will be available to pay for expenditures or obligations incurred by or on behalf of the Participants in accordance with this Agreement. Such minimum amount of Operating Funds may be revised by the Engineering and Operating Committee at any time. The minimum amount of the Operating Funds and any increases therein shall be advanced by the Participants in accordance with the percentages set forth in Section 22, and shall be due and payable within fifteen (15) business days following notification of the establishment of the minimum amount to be kept in Operating Funds or the date on which any increase in such amount authorized by the Engineering and Operating Committee shall become effective. In the event the Engineering and Operating Committee decreases such minimum amount, then each Participant shall receive a credit which shall be equal to the product of its percentage, as set forth in Section 22, and the amount of any such decrease.

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30.3Each Participant shall advance Operating Funds on the basis of notices (hereinafter called bills) submitted by the Operating Agent reflecting such Participant’s share of costs and expenses in accordance with this Agreement, as follows:

30.3.1Expenses described in Sections 30 and 22 shall be billed in writing as follows:

30.3.1.1The payroll costs to be paid to the Operating Agent’s employees for each pay period.

30.3.1.2On the 20th day of each month, the total expenses incurred the previous month and described in Section 22 less those expenses billed under Section 30.3.1.1.

30.3.2Bills submitted under Section 30.3.1 shall be due and payable within seven (7) business days following receipt of the bill.

30.3.3Expenses described in Sections 31 and 23 shall be billed in writing at least ten (10) business days prior to their due date, and funds therefor shall be deposited with the Operating Agent not less than three (3) business days prior to their due date. If such bills do not have a specific due date, they shall be billed within a reasonable time following their incurrence.

30.3.4Expenses described in Sections 7, 26, 27 and 29 shall be billed monthly, except when such expenses exceed the minimum amount in the Operating Funds in which case billing will be made immediately and payable within seven (7) business days following receipt of the bill.

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30.4Except as expressly provided herein, nothing in this Agreement shall be deemed to require the Operating Agent to advance its own monies on any other basis than in its role, if any, as a Participant.

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31.0OPERATING INSURANCE:  

31.1Unless otherwise specified by the Coordination Committee, during the performance of Operating Work, the Operating Agent shall procure and maintain in force, or cause to be procured and maintained in force, policies of Operating Insurance providing coverage against the following risks, hazards and perils:

31.1.1Risks covered by the standard form of commercial liability insurance, including bodily injury, personal injury and property damage risk, hazards of automobiles liability, contractual liability, contractor’s protective liability and liability for products and completed operations, in an amount not less than twenty-five million dollars ($25,000,000).

31.1.2Risks covered by the standard form of “all risk” property insurance providing coverage against all risk of loss, except those risks excluded in the standard form of “all risk” property insurance. Such insurance shall provide boiler and pressure vessel coverage, including reasonable expediting expense.

31.1.3Risks covered by the standard form of workers’ compensation and employers liability insurance, covering employees of the Operating Agent engaged in the performance of Operating Work, or other compliance by the Operating Agent with requirements of the laws of the State of New Mexico as to such coverage.

31.1.4Risks covered by the standard form of employee dishonesty bond covering loss of property or funds due to dishonest or fraudulent acts committed by an officer or employee of the Operating Agent.

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31.2Except for Operating Insurance described in Sections 31.1.3 and 31.1.4, each Participant shall be a named insured individually and jointly and in accordance with its Participation Share as established in Section 6. Operating Insurance referred to in Section 31.1.1 shall carry cross-liability coverage.

31.3In the event that another Participant’s insurance program affords equal or better coverage on a more favorable cost basis than that available to the Operating Agent, the Participants may agree (by separate agreement) that such insurance program may be utilized to afford all or part of the insurance coverage required by Section 31.1.

31.4The insurance company used, the insurable values, limits, deductibles, retentions and other special terms, covenants and conditions of the Operating Insurance shall be agreed upon by the Coordination Committee.

31.4.1Any deductibles shall be shared by the Participants in accordance with the percentages established in Section 22.1.

31.5The Operating Agent shall furnish each of the Participants with either a certified copy of each of the policies of Operating Insurance or a certified copy of each of the policy forms of Operating Insurance, together with a line sheet therefor (and any subsequent amendments) naming the insurers and underwriters and the extent of their participation. When the policies or policy forms of Operating Insurance have been approved in writing by all of the Participants, said policies or policy forms shall not be modified or changed by any Participant without the prior written consent of all of the Participants, except for minor and insubstantial changes or modifications, as to which notification shall be given by the Operating Agent to the Participants.

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31.6Each of the Operating Insurance policies shall be endorsed so as to provide that all named insureds shall be given thirty (30) days notice of cancellation or material change.

31.7Operating Insurance policies shall be primary insurance for all purposes and shall be so endorsed. Any insurance carried by a Participant individually shall not participate with the Operating Insurance as respects any loss or claim for which valid and collectible Operating Insurance shall apply. Such other insurance shall apply solely as respects the individual interest of the Participant carrying such other insurance.

31.8Nothing herein shall prohibit the Operating Agent or any Participant from furnishing a policy of Operating Insurance which combines the coverage required by this Agreement with coverage outside the scope of that required by this Agreement. If the Operating Agent or any Participant furnishes a policy of Operating Insurance which combines the coverage required by this Agreement with coverage outside the scope of that required by this Agreement, the Coordination Committee shall agree on the portion of the total premium cost which is allocable to Operating Insurance. If the Participants are unable to agree on such allocation, the Operating Agent may make an estimated allocation and bill the Participants on the basis thereof, with adjustment to be made when the dispute is resolved.

31.9If a Participant desires changes in any Operating Insurance policy, such Participant shall notify the Operating Agent and the other Participants in writing of the desired changes. Upon agreement of the Coordination Committee to such change, the Operating Agent shall obtain the insurance within sixty (60) days from the date of agreement. If the Operating Agent is unable to obtain the type of policy or coverage required herein or believed by the Operating Agent to be adequate, then the Operating Agent shall immediately notify the Participants.

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31.10In the event the Coordination Committee is unable to agree upon any matters relating to the Operating Insurance, the Operating Agent, pending the resolution of such disagreement, shall procure or cause to be procured such policies of insurance, consistent with Prudent Utility Practice, as are necessary to protect the Participants against the insurable risks for which Operating Insurance is required. During any period of negotiations with an insurer, or other negotiations which are pending at the expiration of the period of coverage of an Operating Insurance policy, or in the event an Operating Insurance policy is canceled, the Operating Agent shall renew or bind policies as an emergency measure, or may procure policies of insurance which are identical to those which were canceled, or may to the extent possible secure replacement policies which will provide substantially the same coverage as the policy expiring or canceled.

31.11Each Participant shall have the right to request that any mortgagee, trustee or secured party be named on all or any of the Operating Insurance policies as loss payees or additional assureds as their interests may appear. Such request shall be submitted to the Operating Agent specifying the name or names of such mortgagee, trustee or secured party and such additional information as may be necessary or required to permit it to be included on the policies of Operating Insurance.

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31.12On an annual basis, the Operating Agent shall advise the Participants on the status of insurance coverage for the San Juan Project and shall make appropriate recommendations concerning insurance issues to the Coordination Committee.

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32.0SURPLUS OR RETIRED PROPERTY:

The Operating Agent shall dispose of surplus property or property no longer used or useful in the operation of the San Juan Project and report such disposal to the Participants, both in accordance with practices and procedures established by the Engineering and Operating Committee. The proceeds from such disposition shall be credited to the Participants in accordance with their Participation Shares.

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33.0REMOVAL OF OPERATING AGENT:

33.1The Operating Agent shall serve as such during the term of this Agreement unless it resigns as Operating Agent by giving notice to the Participants at least one (1) year in advance of the date of resignation or until receipt by the Operating Agent of notice of its removal as provided in Section 33.2.

33.2The Operating Agent may be removed as Operating Agent for any one of the following reasons:

33.2.1The Operating Agent may be removed by action of the Coordination Committee if, in the judgment of the Coordination Committee (voting as provided for in Section 18.4), the best interests of the San Juan Project require that a new Operating Agent be selected. Any Participant seeking a Coordination Committee determination to remove the Operating Agent shall provide to the Operating Agent and to all of the Participants a written statement, detailing the reasons why, in the judgment of the initiating Participant, the Operating Agent should be removed. Within thirty (30) days after receipt by the Operating Agent of this written statement, the Operating Agent shall prepare and serve upon all of the Participants its response which shall contain a detailed rebuttal of the allegations made in the initiating statement. Within the same thirty (30) day period, any other Participant may also prepare and serve upon the Operating Agent and the Participants a statement responding to the allegations in the initiating statement. Within twenty (20) days after service of all such response statements, the Coordination Committee shall meet to consider what action, if any, to take with regard to the removal of the

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Operating Agent. If, pursuant to this Section 33.2.1, the Coordination Committee removes the Operating Agent, such removal shall be effective upon the date established by the Coordination Committee. If the Operating Agent or any Participant is dissatisfied with the action of the Coordination Committee, it shall have the right to seek arbitration under Section 37, but no demand for arbitration shall stay the decision of the Coordination Committee to remove the Operating Agent.

33.2.2If, pursuant to the provisions of Section 34, it is determined that the Operating Agent is in default of its obligations under this Agreement, the Operating Agent may be removed by written notice given by any Participant under Section 34.1.2, which notice shall state the effective date of the removal of the Operating Agent.

33.2.3Notwithstanding the pendency of any actions to remove the Operating Agent, the Operating Agent shall continue in good faith to exercise its obligations as Operating Agent.

33.3Prior to the effective date of a resignation of the Operating Agent, or prior to the date of removal of the Operating Agent in accordance with Section 33.2, the Coordination Committee shall by written agreement designate a new Operating Agent, which may, but need not, be a Participant. The Coordination Committee may designate an interim Operating Agent pending selection of a permanent Operating Agent. Acceptance by the new Operating Agent of its appointment as such shall constitute its agreement to perform the obligations of the Operating Agent under this Agreement.

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34.0DEFAULTS BY OPERATING AGENT:

34.1The following provisions shall apply solely in regard to violations or allegations of violations of this Agreement by the Operating Agent on the basis of which removal of the Operating Agent is sought:

34.1.1In the event any Participant shall be of the opinion that an action taken or failed to be taken by the Operating Agent constitutes a violation of this Agreement, it may give written notice thereof to the Operating Agent and the other Participants, together with a statement of the basis for its opinion. Thereupon, the Operating Agent may prepare a statement of the reasons justifying its action or failure to take action. If agreement in settling the dispute is not reached between the Operating Agent and such Participant which gave such notice, then the matter shall be submitted to arbitration in the manner provided in Section 37. During the continuance of the arbitration proceedings, the Operating Agent may continue such action taken or failed to be taken in the manner it deems most advisable and consistent with this Agreement.

34.1.2If it is determined that the Operating Agent is violating this Agreement, then the Operating Agent shall act with due diligence to end such violation and shall, within thirty (30) days or within such lesser time following the determination as may be prescribed in the determination, take action or commence action in good faith to terminate such violation. In the event that the complaining Participant is of the opinion that the Operating Agent has not taken such action to correct, or to commence action to correct, the violation within such allowed period,

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the complaining Participant shall be entitled to submit the question of the Operating Agent’s good faith action to terminate such violation to arbitration as provided in Section 37. If it is determined that the Operating Agent has not acted with due diligence or good faith to terminate such violation, it shall be deemed to be in default and shall be subject to removal, after the arbitration determination, within fifteen (15) days after receipt of notice executed by the complaining Participant in accordance with Section 42.

34.1.3The provisions of Section 35, excepting Sections 35.8 and 35.9, shall not apply to disputes as to whether or not an action or non-action of the Operating Agent, in its capacity as Operating Agent, is a violation or default under this Agreement.

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PART VII

DEFAULTS, LIABILITY AND ARBITRATION

35.DEFAULTS:

35.1Each Participant shall pay all monies and carry out all other performances, duties and obligations agreed to be paid or performed by it pursuant to all of the terms and conditions set forth and contained in the Project Agreements, and a default by any Participant in the covenants and obligations to be by it kept and performed pursuant to the terms and conditions set forth and contained in any of the Project Agreements shall be an act of default under this Agreement.

35.2In the event of a default by a Participant in any of the terms and conditions of this Agreement to be performed by that Participant, the following shall apply:

35.2.1The Operating Agent shall give a written notice of the default to the defaulting Participant and the other Participants in accordance with Section 35.2.2.

35.2.2The notice of default shall specify the existence, nature and extent of the default. Upon receipt of the notice of default, the defaulting Participant shall immediately take all steps necessary to cure the default as promptly and completely as possible.

35.3In the event that any Participant shall dispute an asserted default by it, then such Participant shall pay the disputed payment or perform the disputed obligation, but may do so under protest. The protest shall be in writing, shall accompany the disputed payment or precede the performance of the disputed obligation(s), and shall specify the reason upon which the protest is based. Copies of such protest shall be mailed by such Participant to all

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other Participants and to the Operating Agent. Payments not made under protest shall be deemed correct, except to the extent that periodic or annual audits may reveal over or under payment by a Participant or may necessitate adjustments. In the event it is determined by arbitration, pursuant to the provisions of this Agreement or otherwise, that the protesting Participant is entitled to a refund of all or any portion of a disputed payment or payments, or is entitled to the reasonable equivalent in money of non-monetary performance of a disputed obligation theretofore made, then, upon such determination, the non-protesting Participant(s) shall reimburse such amount to the protesting Participant, together with interest thereon at the rate of ten percent (10%) per annum, or the maximum legal rate of interest, whichever is lesser, from the date of payment or of the performance of a disputed obligation to the date of reimbursement.

35.4In the event a default shall continue for a period of ten (10) days or more after the notice given by the Operating Agent in accordance with Section 35.2 without having been cured by the defaulting Participant, or without such defaulting Participant having commenced or continued action in good faith to cure such default, the following shall apply:

35.4.1If the defaulting Participant has failed to cure such default or to commence such good faith action during said ten (10) day period, the Operating Agent shall make a written report to the Engineering and Operating Committee concerning the status of the default and shall, on the next working day after such ten (10) day period, notify the defaulting Participant in writing that the Operating Agent intends to declare the defaulting Participant in default under the Project Agreements

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unless there is a prompt cure of the default. Seven (7) days after the giving of such notice to the defaulting Participant, the Operating Agent shall make a second written report to the Engineering and Operating Committee concerning the status of the default and the efforts, if any, of the defaulting Participant to cure the default. If, within seven (7) additional days, the defaulting Participant has neither cured nor reasonably commenced to cure the default, the Operating Agent shall declare the defaulting Participant in default under the Project Agreements and shall provide written notification of the declaration of default to the defaulting Participant and to the Engineering and Operating Committee. Thereafter, and for so long as the default is not remedied and the declaration of default is not revoked by the Operating Agent, all rights of the defaulting Participant under the Project Agreements shall be suspended, including the right to vote on all committees and to receive all or any part of its proportionate share of the Net Effective Generating Capacity.

35.4.2Within seventeen (17) days after the notice by the Operating Agent, as provided for in Section 35.2, the Operating Agent shall prepare special operating procedures for approval by the Engineering and Operating Committee that will apply during the period of suspension under Section 35.4.1. Upon approval by the Engineering and Operating Committee, the Operating Agent shall provide notice to each Participant of such special procedures. These special procedures shall include:

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35.4.2.1A tabulation in form similar to Section 6.2 of the percentages of costs to be borne by the non-defaulting Participants pursuant to Section 35.5;

35.4.2.2Billing and accounting of such costs;

35.4.2.3Dispatch and scheduling of the defaulting Participant’s proportionate share of Net Effective Generating Capacity; and

35.4.2.4Any other items required for the optimal use of the San Juan Project and the mitigation of damages by the non-defaulting Participants.

35.4.2.5If the Operating Agent proposes to broker all or a portion of the defaulting Participant’s proportionate share of Net Effective Generating Capacity on behalf of one or more non-defaulting Participants, the form of such an agreement shall be incorporated in such procedures.

35.4.3Within twenty (20) days after the declaration of a default, as provided for in Section 35.4.1, the defaulting Participant and the non-defaulting Participants shall convene a meeting to address the defaulting Participant’s situation and its intentions with regard to curing its default. The defaulting Participant shall promptly prepare a cure plan for approval by the members of the Coordination Committee entitled to vote thereon. The cure plan shall address the defaulting Participant’s plan to cure the default and restore itself to full participation as an owner of the San Juan Project. The Coordination Committee, by vote of the members of the Coordination Committee entitled to vote thereon, will monitor the defaulting Participant’s compliance with the terms and conditions of the cure plan

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and if it appears to the Coordination Committee that the defaulting Participant is or will be unable to comply with the terms of an approved cure plan, the Coordination Committee shall consider what actions may be required to address such inability, including, but not limited to, directing the Operating Agent to take such actions as may be appropriate. It is the intent of the Participants that any defaults shall be cured on as expeditious a basis as reasonably possible.

35.4.4A demand for arbitration of an asserted default pursuant to Section 37 shall not stay the suspension of the rights of the defaulting Participant, but in the event that the board of arbitrators shall determine that the asserted default did not in fact exist or occur, the arbitrators shall specify a method of fully and fairly compensating the Participant which, under Section 35.4.1, was denied the right to vote on committee actions and to receive all or any part of its proportionate share of the Net Effective Generating Capacity.

35.5During any period when the suspension provided for in Section 35.4.1 is in effect, the non-defaulting Participant(s) having a Participation Share in the affected Unit or Units: (i) shall bear a proportionate share of all expenses, including but not limited to, the operation and maintenance costs, insurance costs, fuel costs, capital expenditures and other expenses otherwise payable by the defaulting Participant under the Project Agreements, including any obligations related to common equipment and facilities, based upon the relation of the Participation Share of each such non-defaulting Participant(s) to the Participation Shares of all non-defaulting Participants in the specific Unit or Units; and (ii) shall be entitled to schedule and receive for their accounts their proportionate share of the Net Effective Generating Capacity of the defaulting Participant.

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35.6In connection with its cure of the default, the defaulting Participant shall pay promptly upon demand to the non-defaulting Participant(s) the total amount of money (and/or the reasonable equivalent in money of non-monetary performance) paid and/or made by such non-defaulting Participant(s) pursuant to Section 35.5 in order to cure any default by the defaulting Participant, together with interest thereon at the rate of ten percent (10%) per annum, or the maximum legal rate of interest, whichever is the lesser, from the date of the expenditure of such money (or the making of such other performance) by the non-defaulting Participant(s), to the date of such reimbursement by the defaulting Participant, or such greater amount as may be otherwise provided in the Project Agreements. Any payment obligation of the defaulting Participant shall be reduced by mitigation measures undertaken by the non-defaulting Participants; provided, however, that the payment obligations of the defaulting Participant shall not be reduced by any profits or gains achieved by the non-defaulting Participants as the result of taking a proportionate share of the Net Effective Generating Capacity due to the default of the defaulting Participant.

35.7The suspension of a defaulting Participant shall be terminated and its full rights under the Project Agreements restored when the default(s) have been cured and all compensable costs incurred by the non-defaulting Participant(s) hereunder have been paid by the defaulting Participant or other arrangements acceptable to the non-defaulting Participant(s) have been made.

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35.8No waiver by a non-defaulting Participant of its rights with respect to a default under this Agreement, or with respect to any other matter arising in connection with this Agreement, shall be effective unless the non-defaulting Participant(s) waive in writing their respective rights and any such waiver shall not be deemed to be a waiver with respect to any subsequent default or matter. No delay short of the statutory period of limitations in asserting or enforcing any right hereunder shall be deemed a waiver of such right.

35.9The rights and remedies provided in this Agreement shall be in addition to the rights and remedies of the Participants as set forth and contained in any other Project Agreement or any rights and remedies the Participants have in law or equity.

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36.0LIABILITY: 

36.1Except for any judgment debt for damage resulting from Willful Action and except to the extent any judgment debt is collectible from valid insurance, and subject to the provisions of Sections 36.1.1, 36.4, 36.5, 36.6 and Section 37, each Participant hereby extends to all other Participants, their directors, members of their governing bodies, officers and employees, its covenant not to execute, levy or otherwise enforce a judgment obtained against any of them, including recording or effecting a judgment lien, for any direct, indirect, or consequential loss, damage, claim, cost, charge or expense, whether or not resulting from the negligence of such Participant, its directors, members of its governing body, officers, employees or any person or entity whose negligence would be imputed to such Participant from (i) Operating Work, the design and construction of Capital Improvements or the use or ownership of the San Juan Project or (ii) the performance or nonperformance of the obligations of any Participant under any of the Project Agreements, other than the obligation to pay any monies becoming due.

36.1.1In the event any insurer providing insurance refuses to pay any judgment obtained by a Participant against any other Parti-cipant, its directors, members of its governing body, officers or employees on account of liability referred to in Section 36.1, the Participant, its directors, members of its governing body, officers or employees against whom the judgment is obtained shall, at the request of the prevailing Participant and in con-sideration for the covenant granted in Section 36.1, execute such documents as may be necessary to effect an assignment of its contractual rights against the nonpaying insurer and thereby give the prevailing

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Participant the opportunity to enforce its judgment directly against such insurer. In no event when a judgment debt is collectible from valid insurance shall the Participant obtaining the judgment execute, levy or otherwise enforce the judgment (including recording or effecting a judgment lien) against the Participant, its directors, members of its governing body, officers or employees against whom the judgment was obtained.

36.1.2To the extent that Section 41-3-5, New Mexico Statutes Annotated, 1978 compilation (as such section may be amended), shall be applicable and for the purpose of relieving each Participant, its directors, members of its governing body, officers and employees of any liability to make contribution to other non-Participant tortfeasors, the foregoing covenant not to execute hereby effects a reduction of all injured Participants’ damages recoverable against all other non-Participant tortfeasors to the extent of the pro rata share (as referred to in Section 41-3-5, New Mexico Statutes Annotated, 1978 compilation, as such section may be amended) of the other Participants, their directors, members of their governing bodies, officers and employees.

36.1.3Each Participant agrees, upon request by any other Participant, to make, execute and deliver any and all documents or take such other action as may reasonably be required to effectuate the intent of this Section 36.1.

36.2Except as provided in Sections 36.4, 36.5 and 36.6, the costs and expenses of discharging all work liability imposed upon one or more of the Participants, for which payment is not made by insurance, shall be allocated among the Participants in proportion to

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their respective Participation Shares in the property giving rise to the work liability. Work liability is defined as liability of one or more Participants for any loss, damage, claim, cost, charge or expense of any kind or nature (including direct, indirect or consequential) suffered or incurred by any party other than a Participant, whether or not resulting or to result in the future from the negligence of any Participant, its directors, members of its governing body, officers, employees or any other person or entity whose negligence would be imputed to such Parti-cipant, that has resulted or may result in the future from (i) performance or nonperformance of the work herein described, (ii) operation, maintenance, use or ownership of the San Juan Project, and (iii) past or future performance or nonperformance of the obligations of any Participant under any of the Project Agree-ments.

36.3If it cannot be determined which property gave rise to work liability, the allocation for discharging costs and expenses associated therewith shall be as specified in Section 22.1.7.

36.4Except for liability resulting from Willful Action (which subject to the provisions of Section 36.6 shall be the responsibility of the willfully acting Participant), any Participant whose electric customer shall have a claim or bring an action against any other Participant for any death, injury, loss or damage arising out of or in connection with electric service to such customer caused by the operation or failure of operation of the San Juan Project or any portion thereof shall indemnify and hold harm-less such other Participant, its directors, members of its governing body, officers and employees from and against any liability for such death, injury, loss or damage.

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36.5Each Participant shall be responsible for any damage, loss, claim, cost, charge or expense that is not covered by insurance and results from its own Willful Action as defined in Section 5.57.2 and shall indemnify and hold harmless the other Participants, their directors, members of their governing bodies, officers and employees, from any such damage, loss, claim, cost, charge or expense.

36.6Except as provided in Section 36.5, the aggregate liability of any Participant to all other Participants for Willful Action not covered by insurance shall be determined as follows:

36.6.1All such liability for damages, losses, claims, costs, charges or expenses of such Participant shall not exceed ten million dollars ($10,000,000) per occurrence. Each Participant extends to each other Participant, its directors, members of its governing body, officers and employees its covenant not to execute, levy or otherwise enforce a judgment against any of them for any such aggregate liability in excess of ten million dollars ($10,000,000) per occurrence.

36.6.2A claim based on Willful Action must be perfected by filing suit in a court of competent jurisdiction within three (3) years after the Willful Action occurs. All claims made thereafter relating to the same Willful Action shall be barred by this Section 36.6.2. The award to each nonwillfully acting Participant from each Participant determined to have committed Willful Action shall be determined as follows:  (i) Each Participant who successfully files suit for remuneration shall receive the lesser of (a) its final judgment awarded (or settlement made) or (b) its pro rata Participation Share of the ten million dollar ($10,000,000)

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maximum recovery established in Section 36.6.1; (ii) When all pending suits are resolved, those Participants who were awarded judgments or reached settlements but whose claims were not fully satisfied pursuant to Sec-tion 36.6.2(i) shall be entitled to participate in any remaining portion of the ten million dollar ($10,000,000) maximum recovery limit, based upon the ratio of the unsatisfied portion of such Participant’s judgment or settlement to the total unsatisfied portion of all such judgments and settlements. Such participation shall be limited to the Parti-cipants’ unsatisfied judgments or settlements.

36.7The provisions of this Section 36 shall not be construed so as to relieve any insurer of its obligation to pay any insurance proceeds in accordance with the terms and conditions of valid and collectible insurance policies.

36.8If a court of competent jurisdiction determines upon a challenge by a Participant or third party that the provisions of Section 56-7-1, New Mexico Statutes Annotated, 1978 Compilation, as amended, are applicable to this Agreement, the Participants agree that any agreement to indemnify contained in this Agreement shall be enforced only to the extent it requires the indemnitor to indemnify or hold harmless the indemnitee, including its officers, employees or agents, against liability, claims, damages, losses or expenses, including attorney’s fees, only to the extent that the liability, damages, losses or costs are caused by, or arise out of, the acts or omissions of the indemnitor or its officers, employees or agents.

133

36.9The Participants agree that the aggregate liability limit of ten million dollars ($10,000,000) referenced in Sections 36.6.1 and 36.6.2 may be determined in the future to be inappropriate and shall, at the request of any Participant, make a good faith effort to evaluate and, if appropriate, revise said limit.

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37.0ARBITRATION:

37.1If a dispute between or among any of the Participants (which term, for purposes of this Section 37, shall be deemed to include the Operating Agent) should arise in relation to any aspect of the San Juan Project, any Participant(s) may call for submission of the dispute to arbitration, which call shall be binding upon all of the other affected Participant(s).

37.2The Participant(s) calling for arbitration shall give written notice to all other Participants, setting forth in such notice in adequate detail the entity(ies) against whom relief is sought, the nature of the dispute, the amount or amounts, if any, involved in such dispute, and the remedy sought by such arbitration proceedings. Within twenty (20) days after receipt of such notice, any other Participant(s) involved may, by written response to the first Participant(s), as well as the other Participant(s), submit its or their own statement of the matter at issue and set forth in adequate detail additional related matters or issues to be arbitrated. Thereafter, the Participant(s) first submitting its or their notice of the matter at issue shall have ten (10) days in which to submit a written rebuttal statement, copies of which shall be provided to all other Participants.

37.3Within ten (10) days following delivery of the last written submittal pursuant to Section 37.2, the affected Participant(s), acting through their respective representatives, shall meet for the purpose of selecting arbitrators. Each affected Participant, or group of Participants, representing one side of the dispute, shall designate an arbitrator. The arbitrators so selected shall meet within twenty (20) days following their selection and shall select additional arbitrator(s), the number of which additional arbitrators shall be one (1)

135

less than the total number of arbitrators selected by the affected Participants. If the arbitrators selected by the affected Participants, as herein provided, shall fail to select such additional arbitrator(s) within said twenty (20) day period, then the arbitrators shall request from the American Arbitration Association (or similar organization if the American Arbitration Association should not exist at the time) a list of arbitrators who are qualified and eligible to serve as hereinafter provided. The arbitrators selected by the affected Participants shall take turns striking names from the list of arbitrators furnished by the American Arbitration Association, and the last name(s) remaining on said list shall be the additional arbitrator(s). All arbitrators shall be persons skilled and experienced in the field which gives rise to the dispute, and no person shall be eligible for appointment as an arbitrator who is an officer or employee of any of the Participants to the dispute or is otherwise interested in the matter to be arbitrated.

37.4Except as otherwise provided in this Section 37 or otherwise agreed by the Participants to the dispute, the arbitration shall be governed by the rules and practices of the American Arbitration Association (or rules and practices of a similar organization if the American Arbitration Association should not exist at that time) from time to time in force, except that if such rules and practices, as modified herein, shall conflict with New Mexico Rules of Civil Procedure or any other provisions of New Mexico law then in force which are specifically applicable to arbitration proceedings, such New Mexico laws shall govern.

37.5Included in the issues which may be submitted to arbitration pursuant to this Section 37 is the issue of whether the right to arbitrate a particular dispute is permitted under the Project Agreements.

136

37.6The arbitrators shall hear evidence submitted by the respective Participants or group or groups of Participants and may call for additional information, which additional information shall be furnished by the party having such information. The decision of a majority of the arbitrators shall be binding upon all the Participants and shall be based on the provisions of the Project Agreements and New Mexico law.

37.7This agreement to arbitrate shall be specifically enforceable and the award of the arbitrators shall be final and binding upon the Participants to the extent provided by the laws of the State of New Mexico. Any award may be filed with the clerk of any court having jurisdiction over the Participants or any of them against whom the award is rendered, and, upon such filing, such award, to the extent permitted by the laws of the jurisdiction in which said award is filed, shall be specifically enforceable or shall form the basis of a declaratory judgment or other similar relief.

37.8Each Participant or group of Participants shall be responsible for the fees and expenses of the arbitrator selected by that Participant or group of Participants, unless the decision of the arbitrators shall specify some other apportionment of such fees and expenses. The fees and expenses of the neutral arbitrators shall be shared among the affected Participants equally, unless the decision of the arbitrators shall specify some other apportionment of such fees and expenses. All other expenses and costs of the arbitration, including attorney fees, shall be borne by the Participant incurring the same.

137

37.9In the event that any Participant(s) shall attempt to institute or to carry out the provisions herein set forth in regard to arbitration, and such Participant(s) shall not be able to obtain a valid and enforceable arbitration decree, such Participant(s) shall be entitled to seek legal remedies in a court having jurisdiction in the premises, and the provisions in this Section 37 referring to arbitration decisions shall then be deemed applicable to final decisions of such court.

138

PART VIII

RETIREMENT AND RECONSTRUCTION

38.0DESTRUCTION, DAMAGE OR CONDEMNATION OF A UNIT:

38.1If all, or substantially all, of a Unit is destroyed, damaged or condemned, then the Participants with Participation Shares in that Unit by unanimous agreement may elect to repair or reconstruct the damaged, destroyed or condemned Unit in such a manner as to restore the Unit to substantially the same general character or use as the original, or to such other character or use as the Participants may then mutually agree. In the event of such election, it shall be the obligation of the Participants to pay for the costs of such repair or reconstruction in accordance with the Participation Shares of the respective Participants in such Unit, and, upon completion thereof, the Participants’ rights, titles and interests therein shall be as provided in this Agreement.

38.2Failure to reach unanimous agreement as provided in Section 38.1 shall be deemed to be an election not to repair or reconstruct the damaged, destroyed or condemned Unit, in which event the proceeds from any insurance or from any award shall be distributed to the Participants in accordance with their respective Participation Shares in such Unit. The facilities not destroyed, damaged or condemned shall be disposed of by the Participants in a manner to be mutually agreed upon, and the proceeds from such disposition shall be distributed in accordance with the Participation Shares of the respective Participants in such Unit. Nothing in this section shall be deemed to preclude any Participant or group of Participants in the Unit from agreeing to repair, reconstruct or replace the damaged, destroyed or condemned Unit.

139

38.3 In the event that less than substantially all of a Unit is destroyed, damaged or condemned, then it shall be the obligation of the Participants having a Participation Share in such Unit to repair or reconstruct such Unit. Each Participant shall be obligated to pay its proportionate share of the costs of such repair or reconstruction in accordance with Section 6.2.

38.4In the event that any common equipment and/or facility is destroyed, damaged or condemned, then it shall be the obligation of the Participants having a Participation Share in such common equipment and/or facilities to repair or reconstruct such damaged, destroyed or condemned equipment and/or facilities. Each Participant shall be obligated to pay its proportionate share of the costs of such repair or reconstruction in accordance with Section 6.2.

140

39.0RIGHTS OF PARTICIPANTS UPON TERMINATION:

39.1 In the event the Participants by unanimous agreement abandon, retire or otherwise terminate or suspend operation of the San Juan Project prior to the termination of this Agreement, the facilities forming the San Juan Project shall be disposed of by the Participants in a manner to be unanimously agreed upon and the proceeds from such disposition shall be distributed to the Participants in accordance with their respective Participation Shares.

141

40.0DECOMMISSIONING OF THE PROJECT:

The Participants acknowledge the appropriateness of incorporating in a future amendment to this Agreement, or in another appropriate contractual instrument, provisions which address the decommissioning of the San Juan Project and/or of one or more Units. It is recognized, however, that the resolution of issues associated with San Juan Project decommissioning will require protracted study. The Participants therefore agree to establish a task force or other forum for the careful and deliberate consideration of decommissioning issues so that these issues may be addressed and resolved in a timely manner. The Operating Agent shall propose to the Participants a methodology and a schedule for addressing decommissioning issues.

142

PART IX

MISCELLANEOUS PROVISIONS

41.0RELATIONSHIP OF PARTICIPANTS:

41.1The covenants, obligations and liabilities of the Participants are intended to be several and not joint or collective, and nothing herein contained shall ever be construed to create an association, joint venture, trust or partnership, or to impose a trust or partnership covenant, obligation or liability on or with regard to any one or more of the Par-ticipants. Each Participant shall be individually responsible for its own covenants, obligations and liabilities as herein provided. No Participant or group of Participants shall be under the control of or shall be deemed to control any other Participant or the Participants as a group. No Participant shall be the agent of or have a right or power to bind any other Participant with-out its express written consent, except as expressly provided herein.

41.2The Participants hereby elect to be excluded from the application of Subchapter “K” of Chapter 1 of Subtitle “A” of the Internal Revenue Code of 1986, or such portion or portions thereof as may be permitted or authorized by the Secretary of the Treasury or its delegate insofar as such subchapter, or any portion or portions thereof, may be applicable to the Parti-cipants hereunder.

143

42.0NOTICES:

42.1Any notice, demand or request provided for in this Agreement, or served, given or made in connection with it, shall be deemed properly served, given or made (i) when delivered personally or by prepaid overnight courier, with a record of receipt, (ii) the fourth day if mailed by certified mail, return receipt requested, or (iii) the day of transmission, if sent by facsimile or telecopy during regular business hours or the day after transmission, if sent after regular business hours (provided however, that such facsimile or telecopy shall be followed on the same day or next business day with the sending of a duplicate notice, demand or request by a nationally recognized prepaid overnight courier with record of receipt), to the persons specified below:

42.1.1Public Service Company of New Mexico

c/o Secretary

Alvarado Square

Albuquerque, New Mexico 87158

42.1.2Tucson Electric Power Company

c/o Secretary

Post Office Box 711

Tucson, Arizona 85702

42.1.3City of Farmington

c/o City Clerk

800 Municipal Drive

Farmington, NM 87401

42.1.4M-S-R Public Power Agency

c/o General Manager

P. O. Box 4060

Modesto, CA 95352

42.1.5Southern California Public Power Authority

c/o Executive Director

225 South Lake Ave, Suite 1250

Pasadena, CA 91101

144

42.1.6City of Anaheim

c/o City Clerk

200 South Anaheim Boulevard

Anaheim, CA 92805

with a copy to:

Public Utilities General Manager

201 South Anaheim Boulevard

Suite 1101

Anaheim, CA 92805

42.1.7Incorporated County of

Los Alamos, New Mexico

c/o Utilities Manager

P.O. Drawer 1030

901 Trinity Drive

Los Alamos, NM 87544

42.1.8Utah Associated Municipal Power Systems

c/o General Manager

2825 E. Cottonwood Parkway

Suite 200

Salt Lake City, UT 84121

42.1.9Tri-State Generation and Transmission

Association, Inc.

c/o Executive Vice President and General Manager

1100 West 116^th Avenue

Westminster, CO 80234

Or P. O. Box 33695

Denver, CO 80233

42.2A Participant may, at any time or from time to time, by written notice to the other Participants, change the designation or address of the person so specified as the one to receive notices pursuant to this Agreement.

42.3The Operating Agent shall provide to each Participant a copy of any material notice, demand or request given or received by it in connection with the San Juan Project.

145

43.0 OTHER PROVISIONS:

43.1Each Participant agrees, upon request by another Participant, to make, execute and deliver any and all documents reasonably required to implement the terms of this Agreement.

43.2No Participant shall be considered to be in default in the performance of any of the obligations hereunder (other than obligations of a Participant to pay costs and expenses) if failure of performance shall be due to uncontrollable forces. The term “uncontrollable forces” shall mean any cause beyond the control of the Participant affected, including but not limited to failure of facilities, flood, earthquake, storm, fire, lightning, epidemic, war, riot, civil disturbance, labor dispute, sabotage, restraint by court order or public authority, or failure to obtain approval from a necessary governmental authority which by exercise of due diligence and foresight such Participant could not reasonably have been expected to avoid and which by exercise of due diligence it shall be unable to overcome. Nothing contained herein shall be construed so as to require a Participant to settle any strike or labor dispute in which it may be involved. Any Participant rendered unable to fulfill any obligation by reason of uncontrollable forces shall exercise due diligence to remove such inability with all reasonable dispatch.

43.3The captions and headings appearing in this Agreement are inserted merely to facilitate reference and shall have no bearing upon the interpretation of the provisions hereof.

43.4This Agreement is made under and shall be governed by the laws of the State of New Mexico, without regard to conflicts of law principles.

146

43.5The covenants and obligations set forth and contained in this Agreement are to be deemed to be independent covenants, not dependent covenants, and the obligation of a Participant to perform all of the obligations and covenants to be by it kept and performed is not conditioned on the performance by another Participant of all of the covenants and obligations to be kept and performed by it.

43.6In the event that any of the terms or conditions of this Agreement, or the application of any such term or condition to any person or circumstance, shall be held invalid by any court having jurisdiction in the premises, the remainder of this Agreement, and the application of such terms or conditions to persons or circumstances other than those as to which it is held invalid, shall not be affected thereby.

43.7All costs or expenses, including all taxes that the Operating Agent is required to pay (but not specifically referred to in other sections of this Agreement), which are incurred by the Operating Agent in connection with the performance of its obligations under this Agreement and which are not specifically allocated to the Participants in accordance with this Agreement shall be equitably allocated among the Participants in a manner to be established by the Coordination Committee.

43.8Should a change in circumstances, economic factors, or basic technology occur which results or may result in a substantial increase or decrease in the benefits to or expenses incurred by a Participant, including the Operating Agent, which such change was not within the reasonable contemplation of the Participants at the time of the execution of this Agreement, the Participants, including the Operating Agent, shall negotiate in good faith in order that an appropriate and equitable adjustment shall be made in the reimbursement of the Operating Agent and in the allocation of expenses among the Participants. Such adjustment shall be fair and equitable as to both the Operating Agent and the other Participants.

147

43.9This Agreement shall be subject to filing with, and to such changes or modifications as may from time to time be directed by, competent regulatory authority, if any, in the exercise of its jurisdiction.

43.10It is the intent of the Participants in executing this Agreement to set out in one instrument the entire agreement of the Participants with respect to the subject matter hereof, and on the effective date hereof to explicitly amend and restate, and to replace in their entirely, the Original San Juan PPA, the Co-Tenancy Agreement, the Operating Agreement and all modifications thereto. Accordingly, on the effective date hereof, the Original San Juan PPA, the Co-Tenancy Agreement and the Operating Agreement are no longer in force and effect except as incorporated herein; provided, however, that the interim coal billing arrangements reflected in side agreements shall continue in effect through their stated term.

43.11The execution of this Agreement shall not affect any rights or obligations of the Participants which shall have accrued prior to the effective date of this Agreement, including any obligation to pay money or take other actions in accordance with the Original San Juan PPA, the Co-Tenancy Agreement, the Operating Agreement or any other agreement.

148

44.0 EXECUTION IN COUNTERPARTS:

44.1This Agreement may be executed in any number of counterparts, and each executed counterpart shall have the same force and effect as an original instrument as if all the Participants to the aggregated counterparts had signed the same instrument. Any signature page of this Agreement may be detached from any counterpart thereof without impairing the legal effect of any signatures thereon and may be attached to any other counterpart of this Agreement identical in form thereto but having attached to it one or more additional pages.

149

45.0AMENDMENTS:

45.1Except as provided in Section 45.2, this Agreement may be amended only by written instrument executed by all of the Participants with the same formality as this Agreement.

45.2The Coordination Committee, by unanimous vote, may amend any one or more of the exhibits attached to this Agreement. In the event of any such action by the Coordination Committee, a copy of the new exhibit shall be attached to this Agreement to replace the old or superseded exhibit, without the necessity of formally amending this Agreement. Any such action shall not affect other provisions of this Agreement, including other exhibits thereto.

150

IN WITNESS WHEREOF, the Participants, by their duly authorized representatives, have caused this Agreement to be made as of this 23rd day of March, 2006.

PUBLIC SERVICE COMPANY

OF NEW MEXICO

By___/s/ Hugh W. Smith ________________

Its Senior Vice President Energy Resources

TUCSON ELECTRIC POWER COMPANY

By___/s/ Michael J. DeConcini ___________

Its SR. V.P. Energy Resources

THE CITY OF FARMINGTON, NEW MEXICO

By___/s/ Maude Grantham-Richards___________

Its Electric Utility Director

M-S-R PUBLIC POWER AGENCY

By___/s/ G. Fraser ________________________

Its General Manager

THE INCORPORATED COUNTY OF LOS ALAMOS,

NEW MEXICO

By___/s/ Robert J. Monday _________________

Its Utilities Manager

151

SOUTHERN CALIFORNIA PUBLIC POWER

AUTHORITY

By__ /s/ Phyllis E. Currie __________________

Its President

CITY OF ANAHEIM

By___/s/ Marcie L. Edwards ________________

Its Public Utilities General Manager

Approved as to Form:

Jack L. White, City Attorney

By___/s/ Lucina Lea Moses ________________

Assistant City Attorney

UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS

By___/s/ Douglas Hunter___________________

Its General Manager

TRI-STATE GENERATION AND TRANSMISSION

ASSOCIATION, INC.

By___/s/ J. M. Shafer______________________

Its Executive VP/General Manager

152

STATE OF NEW MEXICO    )

 )ss.

COUNTY OF BERNALILLO  )

The foregoing instrument was acknowledged before me on this 23 day of March, 2006, by Hugh W. Smith, Senior VP of Public Service Company of New Mexico, a New Mexico corporation, on behalf of the corporation.

/s/ Joni Hardy

Notary Public

My commission expires:

1-26-10

STATE OF ARIZONA)

 )ss.

COUNTY OF PIMA    )

The foregoing instrument was acknowledged before me on this 31st day of January, 2006, by Michael J. DeConcini, SR. V.P., Energy Resources of Tucson Electric Power Company, an Arizona corporation, on behalf of the corporation.

/s/ Melissa R. Martinez__

Notary Public

My commission expires:

7-31-07

153

STATE OF NEW MEXICO   )

 )ss.

COUNTY OF SAN JUAN       )

The foregoing instrument was acknowledged before me on this 9th day of February, 2006, by Maude-Grantham-Richards, Electric Utility Director of The City of Farmington, New Mexico, a New Mexico municipal corporation, on behalf of the municipal corporation.

/s/ Nancy A. Krase

Notary Public

My commission expires:

10/25/08

STATE OF CALIFORNIA       )

   )ss.

COUNTY OF SACRAMENTO)

The foregoing instrument was acknowledged before me on this 18th day of January, 2006, by George Fraser, General Manager of M-S-R Public Power Agency, a California joint powers agency, on behalf of said joint powers agency.

/s/ Kathleen Grindstaff

Notary Public

My commission expires:

July 18, 2008

154

STATE OF NEW MEXICO     )

        )ss.

COUNTY OF LOS ALAMOS)

The foregoing instrument was acknowledged before me on this 3rd day of February, 2006, by Robert J. Monday, Utilities Mgr of The Incorporated County of Los Alamos, New Mexico, a New Mexico Class H County, on behalf of said county.

/s/ Lisa D. Ramos

Notary Public

My commission expires:

5/21/2007

STATE OF CALIFORNIA       )

   )ss.

COUNTY OF LOS ANGELES)

The foregoing instrument was acknowledged before me on this 19^th day of January, 2006, by Phyllis E. Currie, President of Southern California Public Power Authority, a California joint powers agency, on behalf of said joint powers agency.

/s/ Manuel A. Robledo

Notary Public

My commission expires:

1/2/07

155

STATE OF CALIFORNIA         )

 )ss.

COUNTY OF ORANGE )

The foregoing instrument was acknowledged before me on this 1st day of February, 2006, by Marcie L. Edwards, Public Utilities General Manager of the City of Anaheim, a California municipal corporation, on behalf of the said municipal corporation.

/s/ Eugena M. Molina

Notary Public

My commission expires:

November 26, 2006

STATE OF UTAH    )

 )ss.

COUNTY OF SALT LAKE   )

The foregoing instrument was acknowledged before me on this 7th day of Feb., 2006, by Douglas Hunter, General Manager of Utah Associated Municipal Power Systems, a political subdivision of the State of Utah, on behalf of said entity.

/s/ Pamela Beckstead_

Notary Public

My commission expires:

July 8, 2009

156

STATE OF COLORADO  )

 )ss.

COUNTY OF ADAMS     )

The foregoing instrument was acknowledged before me on this 31st day of January, 2006, by J. M. Shafer, Executive Vice President and General Manager of Tri-State Generation and Transmission Association, Inc., a Colorado cooperative corporation, on behalf of the said cooperative corporation.

/s/ Marylin Shaw

Notary Public

My commission expires:

9/4/09

157

REFERENCES TO EXHIBITS IN

PARTICIPATION AGREEMENT

Exhibit No.	References in Agreement	Subject Matter
I	§§ 2.10, 6.1	Real Property
II	§ 5.24	Annual Minimum Coal
III	§§ 5.44, 6.5	Switchyard Facilities
IV	§§ 6.2, 6.2.8	Ownership of Equipment
V	§§ 22.1.7, 22.1.9	O&M of Equipment
VI	§§ 7.11, 22.2.2, 22.6, 22.6.1, 22.7, 22.8
		A&G Expenses
VII	§ 23.3	Coal Allocation and Billing
VIII	§§ 18.4, 19.4, 20.5, 21.4	Adjustment of Voting
IX	§§ 5.19, 23.4.1, 23.4.1.3	Fixed Fuel Expense
X	§§ 5.55, 23.4.1, 23.4.1.3	Variable Fuel Expense

EXHIBIT I

EXHIBIT I TO PARTICIPATION AGREEMENT

This Exhibit I to the Amended and Restated San Juan Project Participation Agreement contains a map of the San Juan Project Generating Station site and the River Weir site, showing Parcels A, B, C, C-1 D, E and F, the parcels of real property underlying the San Juan Project and River Weir sites. Also included in the Exhibit are property descriptions and separate maps showing Parcels A through F. PNM and TEP each has a one-half undivided ownership interest in the parcels described as Parcels A, B, C, D, E and F; and PNM and TEP each has a one-half leasehold interest in Parcel C-1.

Exh. I - 1

PARCEL A

The following portions of Township 30 North, Range 15 West, N.M.P.M., San Juan County, New Mexico:

Section 16:SW 1/4

Section 20:NW 1/4, N 1/2 SE 1/4, SW 1/4SE 1/4

Section 21:NW 1/4 NW 1/4

Section 29:NE 1/4

PARCEL B

The following portions of Township 30 North, Range 15 West, N.M.P.M., San Juan County, New Mexico:

Section 19:SE 1/4 SW 1/4, SW 1/4 SE 1/4

Section 20:E 1/2 NW 1/4, NE 1/4 SW 1/4

Section 29:NW 1/4, N 1/2 SW 1/4

Section 30:NE 1/4, E 1/2 NW 1/4 , N 1/2 SE 1/4

PARCEL C

That part of Lot 6 in Section 4 and of Lot 5 in Section 3, Township 29 North, Range 15 West, N.M.P.M., San Juan County, New Mexico, described as follows:

Beginning at a point which is 772.69 feet, South 88º12’03” East from Northwest Corner of Lot 6:

Thence, S. 55º50’29” E., 205.55 feet; thence, N. 78º21’34” E., 457.06 feet; thence N. 88º29’07” E., 746.61 feet; thence, S. 25º38’00” W., 1,177.50 feet; thence, N. 54º32’00” W., 1,291.70 feet; thence, N. 32º1’00” E., 372.20 feet to the point of beginning. Containing 21.039 acres, more or less.

PARCEL C-1

A tract of land situated adjacent to the southerly side of the San Juan River in Sections 3, 4, 9 and 10, Township 29 North, Range 15 West, N.M.P.M., San Juan County, New Mexico, and more particularly described as follows:

Exh. I - 2

Beginning at point A, from which the corner common to Sections 33 and 34, T.30 N., R. 15 W., and Sections 4 and 3, T. 29 N., R 15 W., bears N. 06º09’45” E., 4,966.7 feet; thence N. 49º00’00” E., 351.95 feet to point B located on the approximate centerline of the San Juan River; thence along the centerline of the River S. 50º44’26” E., 268.63 feet to point C; thence continuing along the centerline of the River, S. 41º18’31” E., 263.59 feet to point D; thence S. 21º12’40” E., 678 feet to point E; thence S. 51º00’00” W., 209 feet to point F; thence N. 39º00’00” W., 1,160.00 feet to the point of beginning; containing 9.376 acres, more or less.

PARCEL D

The following portions of Township 30 North, Range 15 West, N.M.P.M., San Juan County, New Mexico:

Section 17:SE 1/4 SW 1/4, S1/2 SE 1/4

PARCEL E

The following portions of Township 30 North, Range 15 West, N.M.P.M., San Juan County, New Mexico:

Section 19:SE 1/4 SE 1/4

NE 1/4 SE 1/4

E 1/2 NW 1/4 SE 1/4

S 1/2 S 1/2 SE 1/4 NE 1/4

Section 20:SE 1/4 SW 1/4

SW 1/4 SW 1/4

NW 1/4 SW 1/4

S 1/2 SW 1/4 SW 1/4 NW 1/4

Containing 235 acres, more or less.

PARCEL F

The following portions of Township 30 North, Range 15 West, N.M.P.M., San Juan County, New Mexico:

Section 20:SE 1/4 SE 1/4

Exh. I - 3

[Graphic omitted]

San Juan Plant Properties

Overview of Parcel Location

Exh. I - 4

[Graphic omitted]

San Juan Plant Properties

Parcel A

Parcel A as described in Warranty Deed 718/193

Exh. I - 5

[Graphic omitted]

San Juan Plant Properties

Parcel B

Parcel B as described in

Warranty Deed Bk 706/P409

Exh. I - 6

[Graphic omitted]

San Juan Plant Properties

Parcel C and C-1

Parcel C as described in Warranty Deeds 706/407 and 919/398

Parcel C-1 - Navajo Lease dated 7-09-71

Exh. I - 7

[Graphic omitted]

San Juan Plant Properties

Parcel D

Parcel D as described in US Patent 30-81-0006

Exh. I - 8

[Graphic omitted]

San Juan Plant Properties

Parcel E

Parcel E as described in

Warranty Deed 1022/328

Exh. I - 9

[Graphic omitted]

San Juan Plant Properties

Parcel F

Parcel F as described in

Warranty Deed 717/293

Exh. I - 10

EXHIBIT II

EXHIBIT II

EXHIBIT H TO UNDERGROUND COAL SALES AGREEMENT

SAN JUAN STATION MINIMUM DELIVERIES

2003-2017

Column 1	Column 2	Column 3
Year	Minimum Annual Tons	Annual Processing Tons
2003	5,600,000	5,480,500
2004	5,600,000	5,480,500
2005	5,600,000	5,126,000
2006	5,600,000	5,126,000
2007	5,600,000	5,126,000
2008	5,600,000	5,118,000
2009	5,600,000	4,810,000
2010	5,600,000	4,810,000
2011	5,600,000	4,810,000
2012	5,600,000	4,810,000
2013	5,600,000	4,500,000
2014	5,600,000	4,500,000
2015	5,600,000	3,860,000
2016	5,600,000	3,860,000
2017	5,600,000	1,086,500
	84,000,000	68,503,500

Exh. II - 1

EXHIBIT III

EXHIBIT III

SAN JUAN PROJECT SWITCHYARD FACILITIES

Material List

Phase I - Project (DWG, ED-54, ED-55)
QUANTITY	DESCRIPTION
5	345 kV Circuit Breakers - (G.E. A.T.B.’s)
16	345 kV Motor Operated Disconnect Switches with Stands
2	345 kV S&C Circuit Switches with Stands
Lot	Strain Bus and Fittings
Lot	Rigid Bus and Fittings
4	Line Deadend Towers
5	Intermediate Bus Towers
1	Start-Up Transformers 345/12.47/4.16 kV, 24/32/40 MVA
1	Set of 4.16 kV Switchgear
1	4.16 kV Start-Up Cable Run into Plant
2	4.16 kV Station Service Transformers
1	Set of 12.45 kV Switchgear
3	12.47 kV Zig-Zag Grounding Transformer
6	345 kV PCM Potential Transformers with Stands (Bus #1, Bus #2)
6	345 kV Bus Lightning Arresters with Stands
1	Control House 40’ x 72’
2	Sets of Batteries & Chargers, 125 v and 48 v
1	Microwave Tower
Lot	Cable Troughs, Equipment Controls, Breaker Failure Relaying, Fault Recorder
Lot	Metering - Indication, Billing and Telemetry Transducers
Lot	Switchyard Foundations, Fencing, Grading, Grounding
1	Line Trap (FC Line)
1	345 kV PCM Potential Transformer/Coupling Capacitor with Stand
3	345 kV Line Lightning Arresters with Stands
Lot	Line Relaying, Carrier, Microwave
1	345-69-12470 Transformer
1	345/230-12470 Transformer, 230 yard
1	Reactor - 12.47 kV, 345 yard

Exh. III - 1

Phase 2 - Project (DWG. SK-135)
QUANTITY	DESCRIPTION
4	345 kV Circuit Breakers
3	345 kV Motor Operated Disconnect Switches with Stands
Lot	Strain Bus and Fittings
Lot	Rigid Bus and Fittings
1	Intermediate Bus Tower
Lot	Cable Troughs, Equipment Controls, Breaker Failure Relaying
Lot	Metering - Indication, Billing and Telemetry Transducers
Lot	Switchyard Foundations, Grounding
Phase 3 - Project (DWG. SK-316)
3	345 kV Circuit Breakers
6	345 kV Motor Operated Disconnect Switches with Stands
Lot	Strain Bus and Fittings
Lot	Rigid Bus and Fittings
1	Line Deadend Tower
2	Intermediate Bus Towers
Lot	Cable Troughs, Equipment Controls, Breaker Failure Relaying
Lot	Metering - Indication, Billing and Telemetry Transducers
Lot	Switchyard Foundations and Grounding
Phase 3 - Project (DWG. SK-317)
2	345 kV Circuit Breakers
4	345 kV Motor Operated Disconnect Switches with Stands
Lot	Strain Bus and Fittings
Lot	Rigid Bus and Fittings
1	Intermediate Bus Tower
Lot	Switchyard Foundations, Grounding

Exh. III - 2

EXHIBIT IV

EXHIBIT IV(a)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNIT NO. 1

Ownership

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC-	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Start-Up, Unit Auxiliary, and SO2 Scrubber Transformers

11. Bottom Ash System (Up to but not including Dewatering Tank or Ash Water Pump building and equipment.)

12. Fly Ash System

Exh. IV - 1

EXHIBIT IV(a)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the 650-pound Reheat Steam Line and Desuperheater from the Plant Main Steam Line but not including the 165-pound Control Valve and Branch Line to the Chemical Plant

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. SSR Protection System

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

Exh. IV - 2

EXHIBIT IV(b)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNIT NO. 2

Ownership

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC -	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Start-Up, Unit Auxiliary, and SO2 Scrubber Transformers

11. Bottom Ash System (Up to but not including Dewatering Tank or Ash Water Pump building and equipment.)

12. Fly Ash System

Exh. IV - 3

EXHIBIT IV(b)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the 650-pound Reheat Steam Line and Desuperheater from the Plant Main Steam Line but not including the 165-pound Control Valve and Branch Line to the Chemical Plant

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

Exh. IV - 4

EXHIBIT IV(c)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNIT NO. 3

Ownership

PNM -	50%	TEP -	0%
M-S-R -	0%	Farmington -	0%
Tri-State -	8.2%	LAC -	0%
SCPPA -	41.8%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Unit Auxiliary 3A and 3B Transformers*

11. Bottom Ash System including: Hopper, Dewatering Tank, Setting Tank, Surge Tank, Storage Tank, and Pump House

12. Fly Ash System

Exh. IV - 5

EXHIBIT IV(c)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Fuel Oil Ignitor Heaters and Unit Specific Piping

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

19. Coal Reclaim Hoppers, Feeders, Feeder Belts, Belt Scales, Fire Protection System, and 3C Conveyor to the Secondary Crusher Building

20. SSR Protection System

21. Auxiliary Steam Header Piping System:

a. Including the Unit Specific Branch Line to the Reheat System

b. Not included is the Branch Line to the Chemical Plant

* PNM and TEP each owns a 50% interest in the main unit transformer

Exh. IV - 6

EXHIBIT IV(d)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNIT NO. 4

Ownership

PNM -	38.457%	TEP -	0%
M-S-R -	28.8%	Farmington -	8.475%
Tri-State -	0%	LAC -	7.2%
SCPPA -	0%	Anaheim -	10.04%
		UAMPS -	7.028%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Unit Auxiliary 4A and 4B Transformers

11. Bottom Ash System including: Hopper, Dewatering Tank, Setting Tank, Surge Tank, Storage Tank, and Pump House

12. Fly Ash System

Exh. IV - 7

EXHIBIT IV(d)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Fuel Oil Ignitor Heaters and Unit Specific Piping

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

19. Coal Reclaim Hoppers, Feeders, Feeder Belts, Belt Scales, Fire Protection System, and 3D Conveyor to the Secondary Crusher Building

20. Auxiliary Steam Header Piping System:

a. Including the Unit Specific Branch Line to the Reheat System

b. Not included is the Branch Line to the Chemical Plant

Exh. IV - 8

EXHIBIT IV(e)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNITS NO. 1 AND 2

Ownership

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC -	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Bearing Cooling Water System

2. Bottom Ash Dewatering Facility including: Dewatering Tank, Settling Tank, Surge Tank, Storage Tank, and Pump House

3. Demineralizer System including: Clarifier, Storage Tanks, and Sump Pump

4. Fuel Oil System (Fuel Oil for Ignition and Flame Stabilization)

5. Premix Tank Facility (This was the wastewater neutralizer facility and is now operated as part of the Water Management System.)

6. Instrument Air system, except Unit Piping

7. Chemical Feed System, except Unit Piping

a. Condensate and Feedwater System

b. Boiler

c. Bearing Cooling Water System

d. Cooling Tower Systems

e. Chlorination System

8. Plant Air System, except Unit Piping

9. Sootblowing Air System, except Unit Piping

10. Hydrogen Storage System, except Unit Piping

Exh. IV - 9

EXHIBIT IV(e)

(continued)

11. Coal Handling Reclaim Systems A and B including: Hoppers, Feeders, Reclaim Conveyors, Belt Scales, and Sprinkler System

12. Coal Tripper System south of column, Line 12 including Dust Collection System

13. Turbine Lube Oil Storage and Transfer System

14. Control Room, Equipment Rooms, and Associated HVAC System

15. Turbine Crane south of column, Line 12

16. Fuel Oil, Ash, and Water Pipe Racks

17. Boiler Fill System for Units 1 and 2

18. All spare parts common to either unit

19. SO2 Backup Scrubber-Absorber Transformer

20. SAR Multiplexer Control System

Exh. IV - 10

EXHIBIT IV(f)

FACILITIES AND EQUIPMENT SPECIFIC

TO SAN JUAN UNITS NO. 3 AND 4

Ownership

PNM -	44.119%	TEP -	0%
M-S-R -	14.4%	Farmington -	4.249%
Tri-State -	4.1%	LAC -	3.612%
SCPPA -	20.9%	Anaheim -	5.07%
		UAMPS -	3.55%

1. Bearing Cooling Water System

2. Demineralizer System: including Sump Pumps, Filter Beds, and Storage Tanks

3. Fuel Oil System (Fuel Oil for Ignition and Flame Stabilization except Ignitor Heaters and Unit Specific Piping)

4. Wastewater Neutralizer Facility (This facility is operated as part of Water Management System.)

5. Instrument Air System except Unit Piping

6. Chemical Feed System except Unit Piping

a. Condensate and Feedwater System

b. Boiler

c. Bearing Cooling Water System

d. Cooling Tower Systems

e. Chlorination System

7. Plant Air System except Unit Piping

8. Sootblowing Air System except Unit Piping

9. Start-Up Transformers and Nonseg Bus to Units 3 and 4 Switchgear

10. Hydrogen Storage System except Unit Piping

11. Coal Tripper System Serving Units 3 and 4 including Dust Collection Systems

Exh. IV - 11

EXHIBIT IV(f)

(continued)

12. Turbine Lube Oil Storage and Transfer System

13. Control Room, Equipment Rooms, and Associated HVAC System

14. Boiler Fill System for Units 3 and 4

15. Auxiliary Cooling Systems including Auxiliary Cooling Tower No. 1 and Pumps, but excepting No. 4 Tower Pumps and Piping which is Unit Specific

16. CO2 Storage System

17. Start-Up Boiler Feed Pump

18. Turbine Bay Crane north of column, Line 12

19. Fuel Oil, Ash, and Water Pipe Racks

20. Fire Water Booster and Jockey Pumps

21. Halon Fire Protection System

22. Cooling Tower Multiplex Control System

23. All spare parts common to either unit

Exh. IV - 12

EXHIBIT IV(g)

FACILITIES AND EQUIPMENT

COMMON TO ALL FOUR SAN JUAN UNITS

Ownership

PNM -	46.29%	TEP -	19.8%
M-S-R -	8.7%	Farmington -	2.559%
Tri-State -	2.49%	LAC -	2.175%
SCPPA -	12.71%	Anaheim -	3.10%
		UAMPS -	2.169%

1. River and Raw Water System including:

a. Diversion and intake structures, including all equipment and pump building.

b. Raw Water line to reservoir.

c. Reservoir, pump buildings, and all equipment.

d. Raw water lines to plant yard.

e. All above and underground fire protection system to each vendor supplied or unit specific fire protection system.

2. Auxiliary Boiler

3. SO2 Removal System except Absorbers

NOTE: The new SO2 Absorber Feed System is being placed in-service to replace the SO2 Chemical Plant previously used by the Project. The SO2 Chemical Plant facilities will be retired in place and will be salvaged or decommissioned at a later date. Section 3.1 describes the new SO2 Absorber Feed System while Section 3.2 describes the old SO2 Chemical Plant.

3.1SO2 Absorber Feed System

a. Limestone Handling System

b. Limestone Preparation System

c. Dewatering System

d. Gypsum Stack Out System

Exh. IV - 13

EXHIBIT IV(g)

(continued)

3.2SO2 Chemical Plant

a. Double effect evaporator train systems.

b. Fly ash filter system.

c. Absorber product and feed tanks.

d. Condensate collection, storage, and transfer systems.

e. Soda ash storage, mixing, and distribution systems.

f. Sulfate purge system including: crystallizers, centrifuges, evaporators, and salt cake system.

g. Sulfuric acid plant system including storage tanks and load out system.

h. Auxiliary. No. 2 cooling tower, pumps, and systems.

4. Spare-Main Transformer 345/24 kV for all units.

5. Maintenance, Office, and Warehousing Facilities

6. Chemical Laboratory

7. Coal and Ash Handling Control Facilities

8. Roads and grounds such as fencing, yard lighting, guard facilities, drainage, and dikes.

9. Potable Water System

10. Environmental Monitoring systems including Air, Water, and Ground. Excludes Stack Monitoring Systems which are unit specific.

11. Transportation such as trucks, cars, and dozers (not otherwise charged).

12. Water Management System

a. Wastewater Recovery System -- Northside

1. Reverse osmosis system including lime/soda softening clarifier system.

2. Brine concentrator Nos. 4 and 5.

3. Process pond No. 3 and pump system

4. North evaporation ponds 1, 2, and 3.

Exh. IV - 14

EXHIBIT IV(g)

(continued)

b. SO2 Waste Treatment System -- Southside

1. Process ponds 1A, 1 B, 2 and pumping system.

2. Premix tank and clarifier system.

3. Oxidation towers.

4. Brine concentrator Nos. 2 and 3.

5. South evaporation ponds Nos. 1, 2, 3, 4, and 5.

c. Data Acquisition System

d. Solid Waste Disposal Pit

e. Coal pile runoff pond

13. Coal Transfer Facilities from the Reclaim Conveyors to the Head-End of Plat Belts 4A and 4B and Dust Suppression Systems

14. Maintenance Bay Facilities including: Bay Bridge Crane, all Offices, and Support Facilities

15. Sewage Treatment Facilities

16. On each of Units 1 and 2, the Chemical Plant 165-pound Control Valve, and Branch Line from the Unit Specific 650-pound Rehear Steam Line

17. On each of Units 3 and 4, the Chemical Plant Branch Steam Line from the Unit Specific Auxiliary Steam Header System

Exh. IV - 15

EXHIBIT IV(h)

SAN JUAN PROJECT

SWITCHYARD FACILITIES

Cost Allocation (%)

	Installed Cost		Replacements/Improvements Betterments
	PNM	TEP	PNM	TEP
345 kV Bus 1 & 3 (East Bus)	50	50	50	50
Bus 2 (West Bus)	50	50	50	50
Circuit Breakers
06582 (345/230)	50	50	50	50
05482	50	50	50	50
04382 (OJO)	50	50	50	50
12982 (McKinley)	50	50	50	50
11882	50	50	50	50
10782 (Unit 4)	50	50	50	50
09882 (McKinley)	58.33	41.67	62.5	37.5
08782	54.16	45.84	56.25	43.75
07682 (Unit 3)	50	50	50	50
15282 (Four Comers)	50	50	50	50
14182	50	50	50	50
13082 (Unit 2)	50	50	50	50
18582 (West Mesa)	50	50	50	50
17482	50	50	50	50
16382 (Unit 1)	50	50	50	50
20782	50	50	50	50
Shunt Reactors
Ojo	100	0	100	0
McKinley 1	5.36	94.64	5.36	94.64
McKinley 2	16.67	83.33	25	75
WW (BA)	100	0	100	0

Exh. IV - 16

EXHIBIT IV(h)

(continued)

	Installed Cost		Replacements/Improvements Betterments
	PNM	TEP	PNM	TEP
Transformers
Station Aux. No. 2 400 MVA, 345/230-12.5	100	0	100	0
Station Aux. No. 1 345/4.16-12.5	50	50	50	50
Station Aux. No. 3 90 MVA, 345/69-12.5	50	50	50	50
Future Facilities 345/69/12 kV	66.67	33.33	66.67	33.33
2-345 kV Bkrs (Durango)	50	50	50	50
Lower Voltage 230 kV Control Hse	83.33	16.67	83.33	16.67
230/69 kV Trf	66.67	33.33	66.67	33.33
Shiprock 230 kV line	100	0	100	0

Exh. IV - 17

EXHIBIT V

EXHIBIT V(a)

FACILITIES AND EQUIPMENT

SPECIFIC TO SAN JUAN UNIT NO. 1

Operation and Maintenance Costs

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC -	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Start-Up, Unit Auxiliary, and SO2 Scrubber Transformers

11. Bottom Ash System (Up to but not including Dewatering Tank or Ash Water Pump building and equipment)

12. Fly Ash System

Exh. V - 1

EXHIBIT V(a)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the 650-pound Reheat Steam Line and Desuperheater from the Plant Main Steam Line but not including the 165-pound Control Valve and Branch Line to the Chemical Plant

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. SSR Protection System

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

Exh. V - 2

EXHIBIT V(b)

FACILITIES AND EQUIPMENT

SPECIFIC TO SAN JUAN UNIT NO. 2

Operation and Maintenance Costs

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC -	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Start-Up, Unit Auxiliary, and SO2 Scrubber Transformers

11. Bottom Ash System (Up to but not including Dewatering Tank or Ash Water Pump building and equipment)

12. Fly Ash System

Exh. V - 3

EXHIBIT V(b)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the 650-pound Reheat Steam Line and Desuperheater from the Plant Main Steam Line but not including the 165-pound Control Valve and Branch Line to the Chemical Plant

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

Exh. V - 4

EXHIBIT V(c)

FACILITIES AND EQUIPMENT

SPECIFIC TO SAN JUAN UNIT NO. 3

Operation and Maintenance Costs

PNM -	50%	TEP -	0%
M-S-R -	0%	Farmington -	0%
Tri-State -	8.2%	LAC -	0%
SCPPA -	41.8%	Anaheim -	0%
		UAMPS -	0%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Unit Auxiliary 3A and 3B Transformers

11. Bottom Ash System including: Hopper, Dewatering Tank, Setting Tank, Surge Tank, and Pump House

12. Fly Ash System

Exh. V - 5

EXHIBIT V(c)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the Reheat Steam Line from the Auxiliary Steam Header

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Fuel Oil Ignitor Heaters and Unit Specific Piping

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

19. SSR Protection System

20. Auxiliary Steam Header Piping System:

a. Including the Unit Specific Branch Line to the Reheat System

b. Not included is the Branch Line to the Chemical Plant

Exh. V - 6

EXHIBIT V(d)

FACILITIES AND EQUIPMENT

SPECIFIC TO SAN JUAN UNIT NO. 4

Operation and Maintenance Costs

PNM -	38.457%	TEP -	0%
M-S-R -	28.8%	Farmington -	8.475%
Tri-State -	0%	LAC -	7.2%
SCPPA -	0%	Anaheim -	10.04%
		UAMPS -	7.028%

1. Turbine Generator

2. Condenser

3. Condensate and Feedwater System

a. Condensate Pumps

b. Feedwater Heaters

c. Boiler Feed Pumps

d. Storage Tanks

4. Boiler including: Air Heaters, Pulverizers, Bunkers, Feeders and Blowdown Tanks

5. Forced Draft Fans and Primary Air Fans

6. Precipitator

7. Stack and Stack Monitoring System

8. Cooling Tower

9. Circulating Water Pumps

10. Main, Unit Auxiliary 4A and 4B Transformers

11. Bottom Ash System including: Hopper, Dewatering Tank, Setting Tank, Surge Tank, and Pump House

12. Fly Ash System

Exh. V - 7

EXHIBIT V(d)

(continued)

13. Building HVAC System

14. SO2 Absorbers, Scrubbers, Transfer Pumps, Booster Fans, and Flue Gas Reheat System including the Reheat Steam Line from the Auxiliary Steam Header

15. Emergency Diesel Generator

16. Electrical and Control Systems

17. Fuel Oil Ignitor Heaters and Unit Specific Piping

18. Unit Specific Piping for all Air Systems, Chemical Feed Systems, and Hydrogen

19. Auxiliary Steam Header Piping System:

a. Including the Unit Specific Branch Line to the Reheat System

b. Not included is the Branch Line to the Chemical Plant

Exh. V - 8

EXHIBIT V(e)

FACILITIES AND EQUIPMENT

COMMON TO SAN JUAN UNITS NO. 1 AND 2

Operation and Maintenance Costs

PNM -	50%	TEP -	50%
M-S-R -	0%	Farmington -	0%
Tri-State -	0%	LAC -	0%
SCPPA -	0%	Anaheim -	0%
		UAMPS -	0%

1. Bearing Cooling Water System except Unit Piping

2. Bottom Ash Dewatering Facility including: Dewatering Tank, Settling Tank, Surge Tank, Storage Tank, and Pump House

3. Fuel Oil System (Fuel Oil for Ignition and Flame Stabilization)

4. Instrument Air System, except Unit Piping

5. Chemical Feed System, except Unit Piping

a. Condensate and Feedwater System

b. Boiler

c. Bearing Cooling Water System

d. Cooling Tower Systems

e. Chlorination System

6. Plant Air System, except Unit Piping

7. Sootblowing Air System, except Unit Piping

8. Hydrogen Storage System, except Unit Piping

9. Coal Tripper System including Dust Collection System

10. Turbine Lube Oil Storage and Transfer System

11. Control Room, Equipment Rooms, and Associated HVAC System

Exh. V - 9

EXHIBIT V(e)

(continued)

12. SO2 Backup Scrubber-Absorber Transformer

13. Turbine Crane south of column, Line 12

14. Fuel Oil, Ash, and Water Pipe Racks

15. Boiler Fill System

16. SAR Multiplexer Control System

Exh. V - 10

EXHIBIT V(f)

FACILITIES AND EQUIPMENT

COMMON TO SAN JUAN UNITS NO. 3 AND 4

Operation and Maintenance Costs

PNM -	44.119%	TEP -	0%
M-S-R -	14.4%	Farmington -	4.249%
Tri-State -	4.1%	LAC-	3.612%
SCPPA -	20.9%	Anaheim -	5.07%
		UAMPS -	3.55%

1. Bearing Cooling Water System except Unit Piping

2. Fuel Oil System (Fuel Oil for Ignition and Flame Stabilization except Ignitor Heaters and Unit Specific Piping)

3. Instrument Air System except Unit Piping

4. Chemical Feed System except Unit Piping

a. Condensate and Feedwater System

b. Boiler

c. Bearing Cooling Water System

d. Cooling Tower Systems

e. Chlorination System

5. Plant Air System except Unit Piping

6. Sootblowing Air System except Unit Piping

7. Start-Up Transformers and Nonseg Bus to Units 3 and 4 Switchgear

8. Hydrogen Storage System except Unit Piping

9. Coal Tripper System including Dust Collection Systems

10. Turbine Lube Oil Storage and Transfer System

11. Control Room, Equipment Rooms, and Associated HVAC System

Exh. V - 11

EXHIBIT V(f)

(continued)

12. Boiler Fill System

13. Auxiliary Cooling Systems including Auxiliary Cooling Tower No. 1 and Pumps, but excepting No. 4 Tower Pumps and Piping which is Unit Specific

14. CO2 Storage System except Unit Piping

15. Start-Up Boiler Feed Pump except Unit Piping

16. Turbine Bay Crane north of column, Line 12

17. Fuel Oil, Ash, and Water Pipe Racks

18. Fire Water Booster and Jockey Pumps

19. Halon Fire Protection System

20. Cooling Tower Multiplex Control System

Exh. V - 12

EXHIBIT V(g)

FACILITIES AND EQUIPMENT

COMMON TO ALL FOUR SAN JUAN UNITS

Operation and Maintenance Costs

PNM -	46.297%	TEP -	19.8%
M-S-R -	8.7%	Farmington -	2.559%
Tri-State -	2.49%	LAC -	2.175%
SCPPA -	12.71%	Anaheim -	3.10%
		UAMPS -	2.169%

1. River and Raw Water System including:

a. Diversion and intake structures, including all equipment and pump building.

b. Raw Water line to reservoir.

c. Reservoir, pump buildings, and all equipment.

d. Raw water lines to plant yard.

e. All above and underground fire protection system to each vendor supplied or unit specific fire protection system.

2. Auxiliary Boiler

3. SO2 Removal System except Absorbers

NOTE: In April 1998 the new SO2 Absorber Feed System went in-service and replaced the SO2 Chemical Plant previously used by the Project. The SO2 Chemical Plant facilities are retired in place and will be salvaged or decommissioned at a later date. Section 3.1 describes the new SO2 Absorber Feed System while Section 3.2 describes the old SO2 Chemical Plant.

3.1SO2 Absorber Feed System

a. Limestone Handling System

b. Limestone Preparation System

c. Dewatering System

d. Gypsum Stack Out System

Exh. V - 13

EXHIBIT V(g)

(continued)

3.2SO2 Chemical Plant

a.Double effect evaporator train systems.

b.Fly ash filter system.

c.Absorber product and feed tanks.

d.Condensate collection, storage, and transfer systems.

e.Soda ash storage, mixing, and distribution systems.

f. Sulfate purge system including: crystallizers, centrifuges, evaporators, and salt cake system.

g.Sulfuric acid plant system including storage tanks and load out system.

h.Auxiliary No. 2 cooling tower, pumps, and systems.

4. Spare-Main Transformer 345/24 kV for all units.

5. Maintenance, Office, and Warehousing Facilities

6. Chemical Laboratory

7.* Coal and Ash Handling Control Facilities

8. Roads and grounds such as fencing, yard lighting, guard facilities, drainage, and dikes.

9. Potable Water System

10. Environmental Monitoring systems including Air, Water, and Ground. Excludes Stack Monitoring Systems which are unit specific.

11. Transportation such as trucks, cars, and dozers (not otherwise charged).

12. Water Management System

a. Wastewater Recovery System -- Northside

1. Neutralization system including premix tank, neutralization tank, clarifier/thickener, and pumps.

2. Reverse osmosis system including lime/soda softening clarifier system.

3. Brine concentrator Nos. 4 and 5.

4. Process pond No. 3 and pump system.

5. North evaporation ponds 1, 2, and 3.

Exh. V - 14

EXHIBIT V(g)

(continued)

b. SO2 Waste Treatment System -- Southside

1. Process ponds 1A, 1B, 2 and pumping system.

2. Premix tank and clarifier system.

3. Oxidation towers.

4. Brine concentrator Nos. 2 and 3.

5. South evaporation ponds Nos. 1, 2, 3, 4, and 5.

c. Data Acquisition System

d. Solid Waste Disposal Pit

e. Coal pile runoff pond

13.* Coal Handling Equipment -- all equipment from all reclaim hoppers ending at the chutes to the tripper conveyors. This includes: hoppers. feeders. feeder belts, reclaim conveyors, plant conveyors, belt scales, fire protection systems, dust suppression systems, magnetic separators, all electrical and controls, and heating and ventilation systems.

14. Maintenance Bay Facilities including: Bay Bridge Crane, all Offices, and Support Facilities

15. Sewage Treatment Facilities

16. All Demineralizer Systems including: Clarifier, Storage Tanks, Sump Pumps, Filter Beds, and Control Systems.

17. The Chemical Plant 165-pound Control Valve and Branch Line from each of Units 1 and 2 Unit Specific 650-pound Reheat Steam Line.

18. The Chemical Plant Branch Steam Line from (but not including) the Unit Specific Auxiliary, Steam Header System on each of Units 3 and 4.

*Maintenance Only

Exh. V - 15

EXHIBIT V(h)

FACILITIES AND EQUIPMENT

COMMON TO ALL FOUR SAN JUAN UNITS

Operation Costs Only

PNM
M-S-R
TEP	Variable split based on generation by unit
Farmington
Tri-State
LAC
SCPPA
Anaheim
UAMPS

1. Coal and Ash Handling Control Facilities

2. Coal Handling Equipment

All equipment from all reclaim hoppers ending at the chutes to the tripper conveyors. This includes: hoppers, feeders, feeder belts, reclaim conveyors, plant conveyors, belt scales, fire protection systems, dust suppression systems, magnetic separators, all electrical and control, and heating and ventilation systems.

Exh. V - 16

EXHIBIT V(i)

SWITCHYARD FACILITIES AND EQUIPMENT

OPERATION AND MAINTENANCE COSTS

PNM - 65% TEP - 35%

Exh. V - 17

EXHIBIT VI

San Juan Operating Agreement

Exhibit VI-Attachment A

A&G RATIO APPLICABLE TO OPERATION AND MAINTENANCE FOR THE SAN JUAN GENERATING STATION (“SJGS”)

The Operating Agent determines, in accordance with Accounting Practice, the appropriate A&G expense incurred for the benefit of the SJGS and to be billed to the SJGS as follows:

1.A&G expenses directly chargeable by on-site San Juan Project employees as set forth in Section 22.2.2;

2.A&G expenses directly chargeable by A&G related departments located off-site as set forth in Section 22.2.2; and

3.Indirect A&G expenses included in the development of the A&G ratio.

Except as set forth in Section 22.0, individuals located off-site must either charge their time and expenses direct to the SJGS or be included in the A&G pool in the development of the A&G Ratio. Costs incurred for the same purpose must be either all charged direct to the SJGS or all be included in the A&G pool, e.g., all staff persons within the same department must either charge direct to the SJGS or to the A&G pool.

A. The Operating Agent conducts an A&G study every three years. However, periodic reviews will be performed to determine if significant organizational changes have occurred that may require the Operating Agent to conduct an A&G study on a basis more frequently than three years. This study determines the appropriate amount of indirect A&G expense to utilize in the development of the A&G Ratio described below.

The FERC A&G accounts included in the A&G study are: 920, 921, 923, 930.2, 931 and 935.

Background

The responsibility for the SJGS resides in the Operating Agent’s Bulk Power Business Unit. The A&G expenses charged to this Business Unit are derived from two areas. The first component is an allocation of A&G expenses from the Operating Agent’s Corporate Office to the Bulk Power Business Unit. These allocations are based on pre-determined methodologies. The second component of costs are A&G expenses that are directly charged to the Bulk Power Business Unit. Note: Any A&G expenses charged directly to the SJGS are excluded from the determination of the A&G Ratio and are not subject to the A&G Ratio.

Exh. VI - 1

A questionnaire is sent to all managers that have A&G charges to the Bulk Power Business Unit to determine what percentage of their A&G expenses should be included in the development of the A&G Ratio.

The percentages derived from the questionnaires are then applied to the actual A&G amounts charged to the Bulk Power Business Unit for the study year. Amounts are split between labor and other.

B. Labor Ratios for Payroll Taxes (FERC Account 408), Injuries and Damages (FERC Account 925) and Pension and Benefits (FERC Account 926) (See Exhibit VI Attachments B, C and D) are applied to the labor portion of the A&G determined above.

C. Other costs included in the development of the A&G Ratio are Depreciation of General Plant (FERC Account 403), Property Insurance (FERC Account 924) and Property Taxes (FERC Account 408) for the Operating Agent’s headquarters buildings and energy management facility and Amortization of Computer Software (FERC Account 404) for certain software applications that provide benefit to the SJGS.

The portion of the costs related to the Operating Agent’s headquarters buildings included in the development of the A&G Ratio are derived by applying certain ratios obtained from the A&G study questionnaires. The costs included in the A&G Ratio for the Operating Agent’s energy management facility are based on the number of MW of SJGS capacity as a percentage of the Operating Agent’s total generating capacity. In addition, ratios for determining the amount of software costs to include in the A&G Ratio are based on the specific software application. For example, if the Operating Agent installed a new payroll system, the amount of costs for this system that would be included in the A&G Ratio calculation would be based on the number of employees at the SJGS as a percent of the Operating Agent’s total employees. The Operating Agent reviews each specific software application to determine the method for assigning the appropriate amount of costs to be included in the A&G Ratio calculation.

The A&G ratio shall be applied to the following SJGS costs:

1)    Labor charged to the operation and maintenance expenses included in Sections 22.2.1, 22.3, 22.4, 22.5 and 23.3.3 of the San Juan Project Participation Agreement. Such labor dollars are utilized as the denominator in the calculation of the A&G Ratio described below.

The A&G Ratio shall be derived annually based on the preceding year’s experience, as set forth herein unless otherwise agreed to by the participants. The A&G Ratio will be adjusted to actuals at year-end and the adjustment will be used in the computation of the A&G Ratio for the following year.

A&G Ratio = A/B

Exh. VI - 2

Where A = Administrative and general expense chargeable to FERC Accounts 920, 921,

923, 930.2, 931 and 935, including Labor Ratios for Payroll Taxes (FERC Account 408), Injuries and Damages (FERC Account 925) and Pension and Benefits (FERC Account 926) plus other related costs for the Operating Agent’s headquarters buildings and energy management facility for Property Taxes FERC Account (408), Depreciation of General Plant FERC Account (403), and Property Insurance FERC Account (924) plus amortization of certain Computer Software costs charged to FERC Account (404).

B = Total SJGS operation and maintenance labor paid and accrued excluding labor expenses chargeable to FERC accounts 920 through 935 inclusive.

Note:      Any modifications to the methodology utilized for calculating the A&G Ratio described above shall be developed by the San Juan Auditing Committee and approved by the San Juan Coordination Committee.

Exh. VI - 3

San Juan Operating Agreement

Exhibit VI-Attachment B

PAYROLL TAX RATIO FOR THE SAN JUAN GENERATING STATION (“SJGS”)

The Payroll Tax Ratio shall be applied to the following SJGS costs:

1)    Labor charged to operation and maintenance expenses included in Sections 22.2.1, 22.2.2, 22.2.4, 22.2.5 22.3, 22.4, 22.5 and 23.3.3 of the San Juan Project Participation Agreement.

2)    Labor charged to other primary accounts including, but not limited to, FERC Accounts 107, 108, 163, 183, 186 and 188.

The Payroll Tax Ratio shall be determined annually on the basis of the Operating Agent’s preceding years experience adjusted for known changes to comply with regulations applicable to Social Security and Unemployment Compensation as set forth herein unless otherwise agreed to by the participants. The Payroll Tax Ratio will be adjusted to actuals at year-end and the adjustment will be used in the computation of the ratio for the following year.

Payroll Tax Ratio = T/P

Where T = The Operating Agent’s total payroll tax expense chargeable to FERC Account 408.

P = The Operating Agent’s total base labor paid and accrued, less wages paid for time-off allowances plus accruals for time-off allowances.

Notes: (1) Base labor is defined as an employee’s hourly rate times the number of hours worked plus an accrual for time-off allowances. In addition, base labor also includes overtime pay and special pay.

(2)    Time-off allowances are defined as vacation, illness and holiday time.

(3)Special pay is defined as any other compensation an employee receives that is not part of his/her regular base pay. Examples include employee recognition awards as well as results based pay, the Operating Agent’s bonus pay plan.

(4)Any modifications to the methodology utilized for calculating the Payroll Tax Ratio described above shall be developed by the San Juan Auditing Committee and approved by the San Juan Coordinating Committee.

Exh. VI - 4

San Juan Operating Agreement

Exhibit VI-Attachment C

INJURIES AND DAMAGES RATIO FOR THE

SAN JUAN GENERATING STATION (“SJGS”)

The Injuries and Damages Ratio shall be applied to the following SJGS costs:

1)    Labor charged to operation and maintenance expenses included in Sections 22.2.1, 22.2.2, 22.2.4, 22.2.5 22.3, 22.4, 22.5 and 23.3.3 of the San Juan Project Participation Agreement.

2)    Labor charged to other primary accounts including, but not limited to, FERC Accounts 107, 108, 163, 183, 186 and 188.

The Injuries and Damages Ratio shall be determined annually on the basis of the Operating Agent’s preceding year’s experience as set forth herein unless otherwise agreed to by the participants. The Injuries and Damages Ratio will be adjusted to actuals at year-end and the adjustment will be used in the computation of the ratio for the following year.

Injuries and Damages Ratio = I/P

Where I = The Operating Agent’s total injuries and damages expense chargeable to FERC Account 925, including payroll taxes, and pension and benefits on labor chargeable to FERC Account 925. The amount of payroll taxes and pension and benefits to be added are based on the ratios included in Exhibit VI, Attachments B and D, respectively. Note: Any injuries and damages expense charged direct to the SJGS are excluded from the determination of the Injuries and Damages Ratio.

P = The Operating Agent’s total base labor paid and accrued, less wages paid for time-off allowances plus accruals for time-off allowances less special pay and wages charged direct to FERC Account 925.

Notes:        (1)   Special pay is defined as any other compensation an employee receives that is not part of his/her regular base pay. Examples  include employee recognition awards as well as results based pay, the Operating Agent’s bonus pay plan.

(2) Any modifications to the methodology utilized for calculating the Injuries and Damages Ratio described above shall be developed by the San Juan Auditing Committee and approved by the San Juan Coordination Committee.

Exh. VI - 5

San Juan Operating Agreement

Exhibit VI-Attachment D

PENSION AND BENEFITS RATIO FOR THE

SAN JUAN GENERATING STATION (“SJGS”)

The Pension and Benefits Ratio shall be applied to the following SJGS costs:

1)    Labor charged to operation and maintenance expenses included in Sections 22.2.1, 22.2.2, 22.2.4, 22.2.5 22.3, 22.4, 22.5 and 23.3.3 of the San Juan Project Participation Agreement.

2)    Labor charged to other primary accounts including, but not limited to, FERC Accounts 107, 108, 163, 183, 186 and 188.

The Pension and Benefits Ratio shall be determined annually on the basis of the Operating Agent’s preceding year’s experience as set forth herein unless otherwise agreed to by the participants. The Pension and Benefits Ratio will be adjusted to actuals at year-end and the adjustment will be used in the computation of the ratio for the following year.

Pension and Benefits Ratio = B/P

Where B = The Operating Agent’s total pension and benefits expense chargeable to FERC Account 926, including payroll taxes, and injuries and damages on labor chargeable to FERC Account 926. The amount of payroll taxes and injuries and damages to be added are based on the ratios included in Exhibit VI, Attachments B and C, respectively.

P = The Operating Agent’s total base labor paid and accrued, less wages paid for time-off allowances plus accruals for time-off allowances, less overtime, part-time, special pay not eligible for pension and benefits and wages charged direct to FERC Account 926.

Notes:        (1)Special pay is defined as any other compensation an employee receives that is not part of his/her regular base pay. Examples include employee recognition awards as well as results based pay, the Operating Agent’s bonus pay plan. Employee recognition awards are not eligible for pension and benefit loadings.

(2) Any modifications to the methodology utilized for calculating the Pension and Benefits Ratio described above shall be developed by the San Juan Auditing Committee and approved by the San Juan Coordination Committee.

Exh. VI - 6

San Juan Operating Agreement

Exhibit VI-Attachment E

CAPITALIZED A&G RATIO APPLICABLE TO CAPITAL PROJECTS FOR THE SAN JUAN GENERATING STATION (“SJGS”)

The Operating Agent determines the appropriate A&G expense incurred for the benefit of the SJGS and to be billed to the SJGS as follows:

A. The Operating Agent conducts an A&G study every three years. However, periodic reviews will be performed to determine if significant organizational changes have occurred that may require the Operating Agent to conduct an A&G study on a basis more frequently than three years. This study determines the appropriate amount of indirect A&G expense to utilize in the development of the Capitalized A&G Ratio described below.

The FERC A&G accounts included in the A&G study are: 920, 921, 923, 930.2, 931 and 935.

Background

The responsibility for the SJGS resides in the Operating Agent’s Bulk Power Business Unit. The A&G expenses charged to this Business Unit are derived from two areas. The first component is an allocation of A&G expenses from the Operating Agent’s Corporate Office to the Bulk Power Business Unit. These allocations are based on pre-determined methodologies. The second component of costs are A&G expenses that are directly charged to the Bulk Power Business Unit. Note: Any A&G expenses charged directly to the SJGS are excluded from the determination of the Capitalized A&G Ratio. Two Capitalized A&G Ratios are calculated, one for major construction projects (Projects greater than $10,000,000) and one for minor construction projects (Projects less than $10,000,000).

A questionnaire is sent to all managers that have A&G charges to the Bulk Power Business Unit to determine what percentage of their A&G expenses are capital-related and should be included in the development of the Capitalized A&G Ratios. Amounts are split between labor and other.

B. Labor Ratios for Payroll Taxes (FERC Account 408), Injuries and Damages (FERC Account 925) and Pension and Benefits (FERC Account 926) (see Exhibit VI Attachments B, C and D) are applied to the labor portion of the A&G determined above.

The Capitalized A&G Ratios, shall be applied to all SJGS construction costs except for long-term leased transportation and motorized equipment. The total amount of these construction dollars are utilized as the denominator in the calculation of the A&G Ratio described below.

Exh. VI - 7

Capitalized A&G Ratio = A/B

Where A = Administrative and general expense chargeable to FERC Accounts 920, 921, 923, 930.2, 931 and 935, including Labor Ratios for Payroll Taxes (FERC Account 408), Injuries and Damages (FERC Account 925) and Pension and Benefits (FERC Account 926) as categorized separately in the A&G questionnaire for major and minor construction expenditures for the study period.

B = Total SJGS capital project amounts for the Bulk Power Business Unit as categorized between major and minor construction projects for the study period chargeable to FERC Accounts 107 and 108.

Note: Any modifications to the methodology utilized for calculating the A&G Ratio described above shall be developed by the San Juan Auditing Committee and approved by the San Juan Coordination Committee.

Exh. VI - 8

EXHIBIT VII

Example “Interim Invoice”

Example“UG-CSA Invoice”

Example “UPS Invoice”

EXHIBIT VIII

EXHIBIT VIII

Proportional Adjustment of Voting Requirements

in Case of a Default and Suspension of the Rights of a Participant

to Vote Pursuant to Section 35.4.1.

Example Calculation Based on Hypothetical Ownership Percentages:

In the following table, Participant D with Participation Shares in Units 3 and 4 is assumed to be the defaulting Participant. Participation Shares for Voting and Number of Participants for Voting are shown under original or pre-default conditions and are then adjusted as provided in Sections 18.4, 19.4, 20.5, and 21.4 after the right of Participant D to vote is suspended pursuant to Section 35.4.1.

Participation Shares for voting pursuant to Sections 18.4.1(a), 18.4.2(a), and 18.4.3(a) are adjusted as follows:

For Units:

The Adjusted Participation Share for a Participant = (That Participant’s Participation Share)/(The sum of the Participation Shares of all non-defaulting Participants in the affected Unit)

For Common Facilities:

Adjustments related to common facilities shall be proportional to any differing Participation Shares between Units. The above formula would be applied to each Unit and then summed and normalized over the applicable common facilities. Because San Juan Units are of unequal ratings, the normalization will be in proportion to each Unit’s rating rather than the even fractions in the example below where equally sized units were used for simplicity.

The numbers of Participants used for voting purposes pursuant to the requirements of Sections 18.4.1(b), 18.4.2(b), and 18.4.3(b) are adjusted by subtracting the number of defaulting Participants from the total number of Participants voting under those Sections.

Unit or Facility	Original Participation Shares for Voting: §18.4.1(a), §18.4.2(a), and §18.4.3(a)	Original Number of Participants for Voting Purposes: §18.4.1(b), §18.4.2(b), and §18.4.3(b)	Adjusted Participation Shares for Voting - §18.4.1(a), §18.4.2(a), and §18.4.3(a)	Adjusted Number of Participants for Voting Purposes - §18.4.1(b), §18.4.2(b), and §18.4.3(b)
Unit 1		2		2
Participant A	50.00%		50.00%
Participant B	50.00%		50.00%
Unit 2		2		2
Participant A	50.00%		50.00%
Participant B	50.00%		50.00%
Unit 3		4		3
Participant A	20.00%		28.57%1
Participant B	20.00%		28.57%
Participant C	30.00%		42.86%
Participant D	30.00%		0.00%
Unit 4		5		4
Participant A	10.00%		12.50%2
Participant B	10.00%		12.50%
Participant C	20.00%		25.00%
Participant D	20.00%		0.00%
Participant E	40.00%		50.00%
Unit 1 & 2 Common		2		2
Participant A	50.00%		50.00%
Participant B	50.00%		50.00%

 ¹Computed on Unit 3 Participation Shares as follows: (Participant A) / (Participant A + Participant B + Participant C) = 20%/(20%+20%+30%) = 28.57%

²Computed on Unit 4 Participation Shares as follows: (Participant A) / (Participant A + Participant B + Participant C + Participant E) = 10%/(10%+10%+20%+40%) = 12.50%

Exh VIII -2

Unit 3 & 4 Common		5		4
Participant A	15.00%		20.536%3
Participant B	15.00%		20.536%%
Participant C	25.00%		33.928%
Participant D	25.00%		0.00%
Participant E	20.00%		25.000%
Plant Common		5		4
Participant A	32.50%		35.268%4
Participant B	32.50%		35.268%
Participant C	12.50%		16.964%
Participant D	12.50%		0.00%
Participant E	10.00%		12.500%

³Computed on Unit 3 and 4 Common Participation Shares as follows: Unit 3 Contribution = (Participant A) / (Participant A + Participant B + Participant C) = 20%/(20%+20%+30%) = 28.571%; Unit 4 Contribution = (Participant A) / (Participant A + Participant B + Participant C + Participant E) = 10%/(10%+10%+20%+40%) = 12.500%.

Unit 3 & 4 Common = (Unit 3 Rating)/(Sum of Unit 3 and 4 Ratings) * (Unit 3 Contribution) + (Unit 4 Rating)/(Sum of Unit 3 and 4 Ratings) * (Unit 4 Contribution) = ½ (28.571%) + ½ (12.500%) = 20.536%

⁴Computed on Plant Common Participation Shares as follows: Unit 1 Contribution = (Participant A) / (Participant A + Participant B) = 50%/(50%+50%) = 50.000%; Unit 2 Contribution = (Participant A) / (Participant A + Participant B) = 50%/(50%+50%) = 50.000%. Unit 3 Contribution = (Participant A) / (Participant A + Participant B + Participant C) = 20%/(20%+20%+30%) = 28.571%; Unit 4 Contribution = (Participant A) / (Participant A + Participant B + Participant C + Participant E) = 10%/(10%+10%+20%+40%) = 12.500%. Plant Common = (Unit 1 Rating)/(Plant Rating) * (Unit 1 Contribution) + (Unit 2 Rating)/(Plant Rating) * (Unit 2 Contribution) + (Unit 3 Rating)/(Plant Rating) * (Unit 3 Contribution) + (Unit 4 Rating)/(Plant Rating) * (Unit 4 Contribution) = 1/4 (50.000%) + 1/4 (50.000%) + 1/4 (28.571%) + 1/4 (12.500%) = 35.268%

Exh VIII -3

EXHIBIT IX

EXHIBIT IX

FIXED FUEL EXPENSE

SAN JUAN UNDERGROUND COAL SALES AGREEMENT (As Amended)

SECTION 7.3

Reclamation. (Any applicable post-expiration or post-termination reclamation costs described in said section.)

SECTION 8.2(A)

Base CIE Amount

SECTION 8.2(C)

Reimbursable Operating Costs enumerated in Exhibit “F” Paragraph I(1)

SECTION 8.2(D)

Administration Element

SECTION 8.2(E)

That part of CIE Reconciliation Amount associated with Base CIE or Non-SJCC Base CIE

SECTION 8.3(A)

Processing CIE Amount

SECTION 8.3(C)

Processing Administration Element

SECTION 8.3(D)

Processing CIE Reconciliation Amount

SECTION 8.5(A):

Other Reclamation (These are reclamation costs associated with former activities to supply surface-mined coal.)

SECTION 8.5(B)

Substitute REI

SECTION 8.5(C)

Payment of the Utility Payment Stream

SECTION 8.5(D)

Payments under the Ute ROW

SECTION 8.5(E)

Exh IX - 1

Other Miscellaneous Costs

SECTION 8.5(F)

Dispute Costs

COAL SALES AGREEMENT BUY OUT AGREEMENT

SECTION 4.4:

Payment of SJCC Costs

TRANSPORTATION AGREEMENT BUYOUT AGREEMENT

SECTION 3.4:

Payment of SJTC Costs

Any costs allocated as Fixed Fuel Expense pursuant to Section 23.4.1.3 of this Agreement.

Applicable taxes and royalties on the above items shall be deemed Fixed Fuel Expense.

Capitalized Terms used in this Exhibit, not otherwise defined in this Agreement, are as defined in the above captioned agreements.

Exh IX - 2

EXHIBIT X

EXHIBIT X

VARIABLE FUEL EXPENSE

SAN JUAN UNDERGROUND COAL SALES AGREEMENT (As Amended)

SECTION 8.2(B)

Incremental CIE Amount

SECTION 8.2(C)

Reimbursable Operating Costs except those enumerated in Exhibit “F” Paragraph I(1) and only those reclamation costs directly associated with disturbance attributable to the underground mine.

SECTION 8.2(E)

That part of CIE Reconciliation Amount associated with Incremental CIE or Non-SJCC Incremental CIE

SECTION 8.3(B)

Reimbursable Processing Costs

SECTION 8.4

Non-SJCC Coal and Alternate Coal Costs

Capitalized Terms used in this Exhibit, not otherwise defined in this Agreement, are as defined in the above captioned agreements.