Exhibit 10.1

EXECUTION VERSION

NEW EXIT DATE AMENDMENT AMENDING AND RESTATING THE
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
THE INCORPORATED COUNTY OF LOS ALAMOS, NEW MEXICO
UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS

September 1, 2017

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TABLE OF CONTENTS
SECTION                                         PAGE
I. PARTIES AND INTRODUCTORY MATTERS
1
PARTIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . .    1    

2
RECITALS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . .    2    

 
3
AGREEMENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . .     10

4
EFFECTIVE DATE AND TERMINATION . . . . . . . . . . . . . . . . . . . . . . .
.    11

5
DEFINITIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . .     14

II. OWNERSHIP OF SAN JUAN PROJECT
6
OWNERSHIPS AND TITLES . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .    26

7
CAPITAL IMPROVEMENTS AND RETIREMENTS OF SAN JUAN

PROJECT AND PARTICIPANTS’ SOLELY OWNED FACILITIES . . . .    31

8
WAIVER OF RIGHT TO PARTITION . . . . . . . . . . . . . . . . . . . . . . . . . .
. .    36

9
BINDING COVENANTS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .    37

10
MORTGAGE AND TRANSFER OF PARTICIPANTS’ INTERESTS . . .    39

11
RIGHTS OF FIRST REFUSAL . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .    42

12
RIGHTS OF PNM AND TEP IN WATER AND COAL . . . . . . . . . . . . . .        47

13
SEVERANCE OF IMPROVEMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . .
.     48

III. ENTITLEMENTS TO OUTPUT OF SAN JUAN PROJECT
14
ENTITLEMENT TO CAPACITY AND ENERGY . . . . . . . . . . . . . . . . . .     49

15
CAPACITY ALLOCATION OF SWITCHYARD FACILITIES . . . . . . . .        51

16
USE OF FACILITIES DURING CURTAILMENTS . . . . . . . . . . . . . . . . .    53

17
START-UP AND AUXILIARY POWER AND ENERGY

REQUIREMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .     55

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IV. ADMINISTRATION
18
COORDINATION COMMITTEE . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . .    56

19
ENGINEERING AND OPERATING COMMITTEE . . . . . . . . . . . . . . . . .    61

20
FUELS COMMITTEE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .    66

21
AUDITING COMMITTEE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .     72

V. BUDGETS AND OPERATING EXPENSES
22
OPERATION AND MAINTENANCE EXPENSES . . . . . . . . . . . . . . . . . .    76    

23
FUEL COSTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . .     85

24
ANNUAL BUDGETS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .     94

25
PAYMENT OF TAXES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .    95

26
MATERIALS AND SUPPLIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .    96

27
EMERGENCY SPARE PARTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .    98

VI. OPERATING AGENT
28
OPERATION AND MAINTENANCE . . . . . . . . . . . . . . . . . . . . . . . . . . .
.     99

29
OPERATING EMERGENCY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .     105

30
PAYMENT OF EXPENSES BY PARTICIPANTS . . . . . . . . . . . . . . . . . .
    107    

31
OPERATING INSURANCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .     110    

32
SURPLUS OR RETIRED PROPERTY . . . . . . . . . . . . . . . . . . . . . . . . . .
. .    114

33
REMOVAL OF OPERATING AGENT . . . . . . . . . . . . . . . . . . . . . . . . . .
    .    115

34
DEFAULTS BY OPERATING AGENT . . . . . . . . . . . . . . . . . . . . . . . . .
.     .    117

35
DEFAULTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .     .    119

36
LIABILITY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . .     .     126

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37
ARBITRATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . .        131

VIII. RETIREMENT AND RECONSTRUCTION
38
DESTRUCTION, DAMAGE OR CONDEMNATION OF A UNIT. . . . . .    135

39
RIGHTS OF PARTICIPANTS UPON TERMINATION . . . . . . . . . . . . . .        137

40
DECOMMISSIONING OF THE PROJECT . . . . . . . . . . . . . . . . . . . . . . .    
. .    138

40A
EXTENSION OF TERMINATION DATE FOR LARGE CAPITAL

IMPROVEMENT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . .     139

40B
EXTENSION OF TERMINATION DATE AND COAL SUPPLY

AGREEMENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .     . .    142

IX. MISCELLANEOUS PROVISIONS
41
RELATIONSHIP OF PARTICIPANTS . . . . . . . . . . . . . . . . . . . . . . . .    
. .    145

42
NOTICES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .     . .    146

43
OTHER PROVISIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . .     . .    148

44
EXECUTION IN COUNTERPARTS . . . . . . . . . . . . . . . . . . . . . . . . .
.     . .    151

45
AMENDMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . .    152

    
EXHIBIT I                Real Property
EXHIBIT II                [Omitted]
EXHIBIT III                Switchyard Facilities
EXHIBIT IV            Ownership of Equipment
EXHIBIT V                O&M of Equipment
EXHIBIT VI            A&G Expenses
EXHIBIT VII            [Omitted]
EXHIBIT VIII            Adjustment of Voting Requirements

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PART I
PARTIES AND INTRODUCTORY MATTERS
1.0
PARTIES:

The parties to this New Exit Date Amendment Amending and Restating the 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”); 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”); and UTAH ASSOCIATED
MUNICIPAL POWER SYSTEMS, a political subdivision of the State of Utah (“UAMPS”).
As of the effective date hereof, the 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:
2.1    PNM 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.
2.2    TEP is an electric utility engaged in the generation, transmission and
distribution of electric power and energy in a part of the State of Arizona.
2.3    Farmington 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.
2.4    M-S-R Public Power Agency (“M-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.
2.5    LAC 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.
2.6    Southern California Public Power Authority (“SCPPA”) is a public entity
created to acquire, construct, finance, operate and maintain generation and
transmission projects on behalf of its members.
2.7    City of Anaheim (“Anaheim”) operates a municipal utility in the State of
California engaged in the generation, transmission and distribution of electric
power.
2.8    UAMPS is a public entity created to plan, finance, develop, acquire,
construct, improve, better, operate and maintain projects, or ownership
interests or capacity

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rights therein, for the generation, transmission and distribution of electric
energy for the benefit of its members.
2.9    Tri-State Generation and Transmission Association, Inc. (“Tri-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.
2.9(a)    PNMR Development and Management Corporation (“PNMR-D”) is a New Mexico
corporation, a wholly owned subsidiary of PNM Resources, Inc. and an affiliate
of PNM.
2.10    PNM 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.
2.11    PNM 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,

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except for certain provisions which survived through provisions of the
Transportation Agreement Buy Out Agreement.
2.11(a)     PNM entered into a Coal Supply Agreement (“CSA”) for the supply of
all the coal requirements for the San Juan Project from January 1, 2016 through
June 30, 2022. PNM also entered into a Coal Combustion Residual Disposal
Agreement (“CCRDA”), for the performance of all ash disposal activities for the
San Juan Project over the term of the CSA and a Reclamation Services Agreement
(“RSA”), for the performance of all reclamation obligations of the mines that
have supplied coal for the San Juan Project from the RSA’s effective date until
the full release of all reclamation and similar bonds associated with federal
and state leases, agreements and permits. The effective date of the CSA, CCRDA
and RSA was January 31, 2016.
2.11(b)     In connection with the CSA, RSA and CCRDA becoming effective, PNM,
TEP, SJCC and BHP Billiton New Mexico Coal, Inc., parent company to SJCC,
terminated the UG-CSA and the CCBDA by entering into the UG-CSA Termination
Agreement and the CCBDA Termination Agreement.
2.12    PNM 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

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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”).
2.14    The 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

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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”).
2.15    A 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.
2.16    On 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.
2.17    On November 17, 1981, PNM transferred an 8.475 percent undivided
ownership interest in Unit 4 to Farmington.
2.18    On December 31, 1983, PNM transferred a 28.8 percent undivided ownership
interest in Unit 4 to M-S-R.
2.19    On 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”).
2.20    On July 1, 1985, PNM transferred a 7.2 percent undivided ownership
interest in Unit 4 to LAC.
2.21    On July 1, 1993, Century transferred a 41.8 percent undivided ownership
interest in Unit 3 to SCPPA.
2.22    On August 12, 1993, PNM transferred a 10.04 percent undivided ownership
interest in Unit 4 to Anaheim.

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2.23    On June 2, 1994, PNM transferred a 7.028 percent undivided ownership
interest in Unit 4 to UAMPS.
2.24    On 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.
2.26    As of April 29, 1994, PNM, TEP, Century, SCPPA, Farmington, M-S-R, LAC
and Anaheim executed the San Juan Project Designated Representative Agreement,
as amended and restated from time-to-time (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.
2.27    As 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.
2.28    As of March 23, 2006, the participants entered into an Amended and
Restated San Juan Project Participation 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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Certain changes to the Amended and Restated San Juan Project Participation
Agreement were subsequently accepted by FERC for filing as PNM Rate Schedule No.
144.
2.29    The Participants, PNMR-D and the Exiting Participants entered into the
San Juan Project Restructuring Agreement (“Restructuring Agreement”) relating to
the restructuring of ownership interests in the San Juan Project and the
retirement of Units 2 and 3. The Participants, PNMR-D and the Exiting
Participants have also entered into the San Juan Decommissioning and Trust Funds
Agreement (“Decommissioning Agreement”), which relates to decommissioning of the
San Juan Project, and the Amended and Restated Mine Reclamation and Trust Funds
Agreement (“Mine Reclamation Agreement”), which relates to reclamation of the
San Juan Mine.
2.30    Under the terms of the Restructuring Agreement, the Exiting Participants
will terminate their active involvement in the San Juan Project as of the Exit
Date, and as of the Exit Date PNM will (and PNMR-D was to) acquire the San Juan
Project interests of the Exiting Participants.
2.30(a)     Concurrently with the execution of the Restructuring Agreement, the
Participants, PNMR-D and the Exiting Participants entered into the Exit Date
Amendment Amending and Restating the Amended and Restated San Juan Project
Participation Agreement (“Original Exit Date Amendment”). It was contemplated
that the Original Exit Date Amendment would be filed with the FERC prior to the
Exit Date but such filing will not take place.
2.30(b)     The Participants, PNMR-D and the Exiting Participants are parties to
an Assignment, Assumption, Termination and Release Agreement under which PNMR-D
has agreed to assign, and will transfer, to PNM its rights and obligations under
the Restructuring

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Agreement, the Decommissioning Agreement and the Mine Reclamation Agreement.
PNMR-D will therefore no longer become a Participant in the San Juan Project or
be a party to this Agreement.
2.30(c)     In light of the assignment and transfer referenced in Section
2.30(b), this Agreement is entered into to supersede and replace the Original
Exit Date Amendment.
2.31    As of the Exit Date the Exiting Participants will no longer be
Participants in the San Juan Project or parties to this Agreement.

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3.0
AGREEMENT:

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

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4.0
EFFECTIVE DATE AND TERMINATION:

4.1    Except as otherwise provided in Section 4.3, this Agreement shall become
effective upon the effective date established by the FERC in its order accepting
this Agreement for filing; 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 has been issued by the FERC
determining this Agreement to be just and reasonable without changes or
modifications unacceptable to the Participants.
4.2    Following execution, 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 Exit Date, as provided for in the Restructuring Agreement. 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 or shall not take
any action to oppose the filing of this Agreement.
4.3    Following an order by the FERC or any other regulatory agency having
jurisdiction, if any, the Participants shall each review such order, letter or
communication to determine if the FERC 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
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

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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 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 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.
4.4    This Agreement shall continue in force and effect until July 1, 2022,
unless otherwise agreed in writing by the Participants or as provided for in
Sections 40A or 40B.
4.5    The Exiting Participants agree to the amendment of the Amended and
Restated San Juan Project Participation Agreement as provided in this Agreement
to effectuate their removal as participants in the San Juan Project as of the
Exit Date. The Participants agree to such removal and further agree that as of
the Exit Date, the Exiting Participants’ obligations with respect to the San
Juan Project are governed solely by the Restructuring Agreement, the Mine
Reclamation Agreement and the Decommissioning Agreement.
4.6    PNMR-D agrees to the amendment of the Amended and Restated San Juan
Project Participation Agreement to reflect the assignment and transfer to PNM of
PNMR-D’s

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rights and obligations under the Restructuring Agreement, the Decommissioning
Agreement and the Mine Reclamation Agreement and to reflect PNMR-D’s removal as
a Participant.

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5.0    DEFINITIONS:
The following terms, when used herein with initial capitalization, and whether
in the singular or the plural, shall have the meaning specified:
5.1    ACCOUNTING PRACTICE: Generally accepted accounting principles in
accordance with FERC Accounts applicable to electric utility operations.
5.2    AGREEMENT: This New Exit Date Amendment Amending and Restating the
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.
5.3    AUDITING COMMITTEE: A committee which is described in Section 21.
5.4    AVAILABLE 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.
5.4(a)    AVAILABLE PRE-EXISTING STOCKPILE TONS has the meaning provided for in
Section 12.1(C)(1) of the CSA.
5.5    CAPACITY: Electrical rating expressed in megawatts (“MW”).
5.6    CAPITAL 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.
5.6(a)    CBI means capital budget item.

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5.6(b)    CCBDA means the Coal Combustion Byproducts Disposal Agreement between
PNM, TEP and SJCC, which was terminated by the CCBDA Termination Agreement.
5.6(c)    CCBDA TERMINATION AGREEMENT means the Coal Combustion Byproducts
Disposal Agreement Termination and Mutual Release Agreement between SJCC, BHP
Billiton, PNM and TEP.
5.6(d)    CCR means ash and gypsum byproducts produced by the San Juan Project.
5.6(e)    CCRDA means the Coal Combustion Residuals Disposal Agreement entered
into between PNM and Westmoreland Coal Company with an effective date of January
31, 2016.
5.7    COAL 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.
5.8    COAL 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.
5.8(a)    COAL TONNAGE COMPONENT means coal tonnage categories as defined in the
CSA and comprised of Pre-existing Stockpile Coal, Force Majeure Tons, Available
Pre-existing Stockpile Tons, Tier 1 Tons and Tier 2 Tons.
5.9    COMMON PARTICIPATION SHARE: Each Participant’s percentage ownership
interest as set forth in Section 6.2.6.

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5.10    CONTROL 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.
5.11    COORDINATION COMMITTEE: A committee which is described in Section 18.
5.12    CO-TENANCY AGREEMENT: The agreement described in Section 2.13.
5.12(a)     CSA means the Coal Supply Agreement entered into between PNM and
Westmoreland Coal Company with an effective date of January 31, 2016, as may be
amended or replaced.
5.12(b)     DECOMMISSIONING AGREEMENT means the San Juan Project Decommissioning
and Trust Funds Agreement among the Participants, PNMR-D and the Exiting
Participants executed concurrently with the Restructuring Agreement and
effective on the Exit Date.
5.13     DR AGREEMENT: The agreement described in Section 2.26, as amended from
time to time.
5.14    EMERGENCY 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.
5.15    EMERGENCY 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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5.16    ENERGY: The accumulated amount of power produced over a stated time
interval, expressed in kilowatt hours (“kWh”) or megawatt hours (“MWh”).
5.17    ENGINEERING AND OPERATING COMMITTEE: A committee which is described in
Section 19.
5.17(a)    EXIT DATE means the date upon which the Exiting Participants transfer
all of their respective rights, titles and interests in and to their Ownership
Interests to PNM, as provided in the Restructuring Agreement and in the
Assignment, Assumption, Termination and Release Agreement, and terminate their
active involvement in the operation of the SJGS, except as expressly provided
for in the Restructuring Agreement, the Mine Reclamation Agreement and the
Decommissioning Agreement; the Exit Date will be on or about December 31, 2017.
5.17(b)    EXITING PARTICIPANTS means those entities that will transfer all of
their respective rights, titles and interests in and to their Ownership
Interests to PNM on the Exit Date and terminate their active involvement in the
operation of SJGS on the Exit Date, except as expressly provided for in the
Restructuring Agreement, the Mine Reclamation Agreement and the Decommissioning
Agreement; the Exiting Participants are M-S-R, Anaheim, SCPPA and Tri-State.
5.18    FC LINE:    That 345 kV transmission line between the San Juan
generating station and the Four Corners generating plant.
5.19     [Omitted]
5.20    FERC:    The Federal Energy Regulatory Commission or any successor
thereto.

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5.21    FERC 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.
5.21(a)    FORCE MAJEURE TONS has the meaning provided for in Section 12.1(C)(3)
of the CSA.
5.22    FUELS COMMITTEE: A committee which is described in Section 20.
5.22(a)    LARGE CAPITAL IMPROVEMENT has the meaning provided for in Section
18.4.4.
5.22(b)    LEGACY COSTS means those costs payable under Sections 8.2, 8.3 and
8.4 of the CSA.
5.23    MATERIALS 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.
5.23(a)     MINE RECLAMATION AGREEMENT means the Amended and Restated Mine
Reclamation and Trust Funds Agreement among the Participants, PNMR-D and the
Exiting Participants executed concurrently with the Restructuring Agreement.
5.24    [Omitted]
5.25    MINIMUM NET GENERATION: The lowest net load at which each Unit can be
reliably maintained in service on a continuous basis on coal fuel.
5.26    [Omitted]
5.27    NET EFFECTIVE GENERATING CAPACITY: The maximum continuous ability of
each Unit to produce power, less auxiliary power requirements.

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5.28    NET ENERGY GENERATION: The Energy generated by each Unit which is
available to the respective Participants at the 345 kV bus.
5.29    OPERATING ACCOUNT:    The bank account(s) in the names of the
Participants established by the Operating Agent pursuant to Section 28.
5.30    OPERATING 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.
5.31    OPERATING AGREEMENT: The agreement described in Section 2.14.
5.32    OPERATING 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.
5.33    OPERATING FUNDS: Monies advanced to, and disbursed by, the Operating
Agent on behalf of the Participants in accordance with this Agreement.
5.34    OPERATING INSURANCE: Policies of insurance secured or to be secured and
maintained in accordance with Section 31.
5.35     OPERATING 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, the Restructuring
Agreement and of any Project Agreements, environmental compliance activities and
the procurement of fuel and water and other necessary materials and supplies.

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5.36    ORIGINAL SAN JUAN PPA: The San Juan Project Participation Agreement
dated October 27, 1999.
5.36(a)     OWNERSHIP INTEREST means a Participant’s percentage undivided
ownership interest in a Unit and in common equipment and facilities and as
increased, decreased, acquired or transferred as provided in Sections 6.3 and
6.4 of the Restructuring Agreement and the Assignment, Assumption, Termination
and Release Agreement, and rights incidental thereto.
5.37    PARTICIPANT: PNM, TEP, Farmington, LAC or UAMPS.
5.38    PARTICIPANT COAL CONSUMPTION:    Each Participant’s total San Juan
Project coal consumption in tons as determined by the Operating Agent. 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.
5.39    PARTICIPATION SHARE: Each Participant’s percentage ownership interest in
the various elements of the San Juan Project as set forth in Section 6.
5.39(a)    PRE-EXISTING STOCKPILE COAL means coal that as of the effective date
of the Restructuring Agreement is stockpiled on SJCC property.
5.40    PROJECT AGREEMENTS: Other than the Restructuring Agreement,
Decommissioning Agreement and Mine Reclamation Agreement, which are not Project
Agreements, Project Agreements will be 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.

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5.41    PROJECT COAL INVENTORY:    The sum of coal in coal storage piles, silos,
conveying systems, hoppers, and all other coal storage at the San Juan Project
as accounted in FERC Account No. 151.
5.42    PRUDENT 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 CSA
or successor agreement, the rights and obligations of the Participants in
accordance with this Agreement and any other special circumstances affecting the
Operating Work.
5.42(a)     REMAINING PARTICIPANTS means those Participants that will continue
participation in the San Juan Project on and after the Exit Date; the Remaining
Participants are PNM, TEP, Farmington, UAMPS and LAC.
5.42(b)     RESTRUCTURING AGREEMENT means the San Juan Project Restructuring
Agreement among the Participants, PNMR-D and the Exiting Participants.
5.42(c)     RSA means the Reclamation Services Agreement entered into between
PNM and Westmoreland Coal Company with an effective date of January 31, 2016.
5.43     SAN JUAN PROJECT or SAN JUAN GENERATING STATION (“SJGS”): The four
unit, coal-ired electric generation plant located in San Juan County,

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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 (only two units of which will be operational
after the Exit Date). The San Juan Project does not include distribution lines,
transmission lines, equipment in the Switchyard Facilities or other facilities
owned exclusively by a Participant.
5.43(a)    SJGS means the San Juan Generating Station.
5.43(b)    SJCC means San Juan Coal Company, a Delaware corporation, or its
successors or assigns.
5.44    SWITCHYARD FACILITIES: The switchyard facilities required for the San
Juan Project as shown by materials listed in Exhibit III, attached hereto and
incorporated herein.
5.44(a)    TIER 1 TONNAGE ALLOCATION means a schedule allocating Tier 1 Tons on
a monthly basis based on the SJGS monthly planned coal consumption.
5.44(b)    TIER 1 TONS means, with respect to: (i) each of 2016 and 2017, 5.750
million tons; (ii) each of 2018 and 2019, 2.8 million tons; (iii) each of 2020
and 2021, 2.65 million tons; and (iv) in 2022, 1.4 million tons.
5.44(c)    TIER 2 TONS means all tons delivered to and accepted by SJGS in a
year in excess of Tier 1 Tons.
5.45    [Omitted]
5.46    TRANSPORTATION 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, which terminated the Transportation
Agreement with SJTC dated April 30, 1984.

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5.46(a)    UG-CSA TERMINATION AGREEMENT means the Underground Coal Sales
Agreement Termination and Mutual Release Agreement among PNM, TEP, SJCC and BHP
Billiton New Mexico Coal.
5.47    UNDERGROUND COAL SALES AGREEMENT: Agreement between PNM, TEP and SJCC
executed on August 31, 2001, as amended or modified, which was terminated by the
UG-CSA Termination Agreement.
5.48    UNIT: Unit 1, Unit 2, Unit 3 or Unit 4.
5.49    UNIT 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 340 MW.
5.50    UNIT 2: The first operating unit of the San Juan Project, which was
placed in commercial service on November 30, 1973 and which has been retired
from service.
5.51    UNIT 3: The third operating unit of the San Juan Project, which was
placed in commercial service on December 31, 1979 and which has been retired
from service.
5.52    UNIT 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.
5.53    UNITS 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.
5.54    [Omitted]

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5.55     [Omitted]
5.56    WATER 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.
5.57    WILLFUL ACTION:
5.57.1    Action 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
5.57.2    Action 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
5.57.3    Action 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

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taken or not taken with the knowledge that such action taken or not taken is a
material default under a Project Agreement.
5.57.4    The 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.
5.57.5    Willful 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
6.0    OWNERSHIPS AND TITLES:
6.1    PNM 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.
6.2    Unless 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:
6.2.1    For Units 1 and 2 and for all equipment and facilities directly related
to Units 1 and 2 only, in accordance with the following percentages:

6.2.1.1    PNM:         50 percent
6.2.1.2    TEP:         50 percent
6.2.1.3    [Omitted]            
6.2.1.4    Farmington:      0 percent
6.2.1.5    [Omitted]
6.2.1.6    LAC:          0 percent
6.2.1.7    [Omitted]
6.2.1.8    [Omitted]
6.2.1.9    UAMPS:          0 percent
6.2.2    For Unit 3 and for all equipment and facilities directly related to
Unit 3 only, in accordance with the following percentages:

6.2.2.1    PNM:         100 percent
6.2.2.2    TEP:         0 percent
6.2.2.3    [Omitted]
6.2.2.4    Farmington:     0 percent
6.2.2.5    [Omitted]
6.2.2.6    LAC:         0 percent
6.2.2.7    [Omitted]
6.2.2.8    [Omitted]
6.2.2.9    UAMPS:         0 percent

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

6.2.3.1    PNM:          77.297 percent
6.2.3.2    TEP:          0 percent
6.2.3.3    [Omitted]
6.2.3.4    Farmington:      8.475 percent
6.2.3.5    [Omitted]
6.2.3.6    LAC:          7.20 percent
6.2.3.7    [Omitted]
6.2.3.8    [Omitted]
6.2.3.9    UAMPS:          7.028 percent
6.2.4    For equipment and facilities common to Units 1 and 2 only, in
accordance with the following percentages:

6.2.4.1    PNM:         50 percent
6.2.4.2    TEP:         50 percent
6.2.4.3    [Omitted]
6.2.4.4    Farmington:     0 percent
6.2.4.5    [Omitted]
6.2.4.6    LAC:         0 percent
6.2.4.7    [Omitted]
6.2.4.8    [Omitted]
6.2.4.9    UAMPS:         0 percent
6.2.5    For equipment and facilities common to Units 3 and 4 only, in
accordance with the following percentages:

6.2.5.1    PNM:         77.297 percent
6.2.5.2    TEP:          0 percent
6.2.5.3    [Omitted]
6.2.5.4    Farmington:      8.475 percent
6.2.5.5    [Omitted]
6.2.5.6    LAC:          7.200 percent
6.2.5.7    [Omitted]
6.2.5.8    [Omitted]
6.2.5.9    UAMPS:          7.028 percent

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

6.2.6.1    PNM:         66.344 percent
6.2.6.2    TEP:         20.068 percent
6.2.6.3    [Omitted]
6.2.6.4    Farmington:     5.076 percent
6.2.6.5    [Omitted]
6.2.6.6    LAC:         4.309 percent
6.2.6.7    [Omitted]
6.2.6.8    [Omitted]
6.2.6.9    UAMPS:         4.203 percent
6.2.7    San 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 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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6.2.8    Exhibit 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.
6.2.9    In 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.
6.2.10    Materials and Supplies shall be owned by the Participants in
proportion to their respective current investments in the Materials and
Supplies.
6.3    Upon the effective date of this Agreement, the Emergency Coal Storage
Pile shall be owned as follows:

6.3.1    PNM:         73.297 percent
6.3.2    TEP:         19.8 percent
6.3.3    [Omitted]
6.3.4    Farmington:     2.559 percent
6.3.5    [Omitted]
6.3.6    LAC:         2.175 percent
6.3.7    [Omitted]
6.3.8    [Omitted]
6.3.9    UAMPS:     2.169 percent
6.4    In 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

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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.
6.5    PNM 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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7.0    CAPITAL IMPROVEMENTS AND RETIREMENTS OF SAN JUAN PROJECT AND
PARTICIPANTS’ SOLELY OWNED FACILITIES:
7.1    The 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.
7.2    Any such Capital Improvements and retirements shall be noted by an
appropriate revision in or supplement to the appropriate exhibits hereto
attached.
7.3    The 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.
7.4    All 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.
7.5    The 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 monthly expenditures from those previously forecast
are anticipated. The Operating Agent

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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).
7.6    In 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, unless otherwise provided in the Decommissioning Agreement, 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 on the best available terms
as soon as practicable.
7.7    Each 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, and that 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 conditions on a Participant allowed to
make such additions in order to protect the other Participants

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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.
7.8    Each 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.
7.9    Transportation 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 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

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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.
7.10    Upon 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.
7.11    Administrative 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 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.

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

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8.0
WAIVER OF RIGHT TO PARTITION:

8.1    The 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:
8.1.1    That 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
8.1.2    That 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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9.0
BINDING COVENANTS:

9.1    Except 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:
9.1.1
Each Participant;

9.1.2    All 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;
9.1.3    All receivers, assignees for the benefit of creditors, bankruptcy
trustees and referees of a Participant;
9.1.4    All other persons, firms, partnerships or corporations claiming through
or under any of the foregoing; and
9.1.5    Any 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

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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.
9.2    The 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.
9.3    Any 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.
9.4    In 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.
9.5    Nothing 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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10.0
MORTGAGE AND TRANSFER OF PARTICIPANTS’ INTERESTS:

10.1    The 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.
10.2    Any 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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10.3    Except 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.
10.4    Each 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:
10.4.1    To any corporation or other entity acquiring all or substantially all
of the property of such Participant; or
10.4.2    To any corporation or entity into which or with which such Participant
may be merged or consolidated; or
10.4.3    To any corporation or entity the stock or ownership of which is wholly
owned by a Participant; or
10.4.4    To any corporation or other entity which owns all of the outstanding
common stock or other ownership interest of a Participant (its “Parent”); or
10.4.5    To any corporation or other entity the common stock or other ownership
interest of which is wholly owned by the Parent of a Participant.
10.5    Except 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

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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.
10.6    No 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.
10.7    Except 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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11.0
RIGHTS OF FIRST REFUSAL:

11.1    The 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 appropriate
instruments. Nothing in this Section 11 shall be construed to limit or expand
the rights of first refusal of any Participant.
11.2    Except 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:
11.2.1    Where 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

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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
11.2.2    Where 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 purchase price shall be 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.
11.3    At 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

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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.
11.4    The Participants 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.
11.5    When 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:
11.5.1    The 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;
11.5.2    The 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
11.5.3    A 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.

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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.
11.6    If 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 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.
11.7    No 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

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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.
11.8    Any 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.
11.9    The 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.
11.10    A 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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12.0
RIGHTS OF PNM AND TEP IN WATER AND COAL:

12.1    If, 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, 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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13.0
SEVERANCE OF IMPROVEMENTS:

13.1    All 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
14.0
ENTITLEMENT TO CAPACITY AND ENERGY:

14.1    Subject to the provisions of Section 16, the Participants shall be
entitled to the Net Effective Generating Capacity of each of Unit 1 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.
14.2    The Operating Agent shall keep the system dispatcher of each Participant
advised of the Available Operating Capacity.
14.3    When 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.
14.4    The 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.
14.5    The 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

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may be revised from time to time, as long as such schedules do not jeopardize
the operation of the San Juan Project.
14.6    The 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.
14.7    The 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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15.0
CAPACITY ALLOCATION OF SWITCHYARD FACILITIES:

15.1    The 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.
15.1.1    The transmission capacity of the FC Line shall be measured at the Four
Corners terminal. PNM and TEP each shall be entitled to fifty percent (50%) of
the designated FC Line Capacity.
15.1.2    The transmission capacity of the FC Line termination and other
contract matters concerning the Four Corners Project shall be handled
individually by PNM and TEP.
15.2    The 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;
No. 7:    Western Area Power Administration-Shiprock 345 kV transmission line.

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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.
15.2.2    The 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.
15.2.3    Any 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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16.0
USE OF FACILITIES DURING CURTAILMENTS:

16.1    If the Net Effective Generating Capacity of Units 1 and 4 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 such 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.
16.2    If 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.
16.3    [Omitted]
16.4    To 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.
16.5    Curtailment 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.

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16.6    No 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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17.0
START-UP AND AUXILIARY POWER AND ENERGY REQUIREMENTS:

17.1    Each 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
18.0
COORDINATION COMMITTEE:

18.1    As 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.
18.2    The 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.
18.3    The Coordination Committee shall have the following functions and
responsibilities:
18.3.1    Provide liaison between and among the Participants.

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18.3.2    Exercise general supervision over the Engineering and Operating
Committee, the Fuels Committee and the Auditing Committee.
18.3.3    Consider and act upon all matters referred to the Coordination
Committee by the Engineering and Operating Committee, the Fuels Committee and
the Auditing Committee.
18.4    Any action or determination of the Coordination Committee shall require
a vote of the Participants in accordance with Sections 18.4.1, 18.4.2, 18.4.3 or
18.4.4. 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, 18.4.3 or
18.4.4 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.
18.4.1    Except as provided in Sections 18.4.2, 18.4.3 and 18.4.4, any actions
or determinations brought before the Coordination Committee shall require the
following vote:
(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

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(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.
18.4.2    Any 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 CSA, replacement of the CSA with a new agreement or any
interim coal pricing agreement related to the CSA (or its successor) shall
require the following vote:
(a)    More than an eighty-two percent (82%) majority of the Common percentages
of the Participants; and
(b)    A minimum of sixty-six and two thirds percent (66 2/3%) majority of the
number of individual Participants.
18.4.4    Any action or determination of the Coordination Committee regarding
individual capital projects with a cost greater than fifty million dollars
($50,000,000) (“Large Capital Improvement”) shall require unanimous approval of
the representatives on the Coordination Committee. Prior to presenting a capital
budget item (“CBI”) for a Large Capital Improvement, the Operating Agent shall

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provide timely financial analysis to the Participants justifying the proposed
capital expenditure for the Large Capital Improvement. If one or more of the
Participants abstains from voting on the CBI for any Large Capital Improvement,
approval of such CBI shall require the affirmative vote of all of the
Participants that have voted.
18.5    The 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.
18.6    Except for matters subject to the voting requirements of Sections
18.4.3, 18.4.4 and 40A, 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

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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.
18.7    In 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 Participant which is a signatory to the CSA
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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19.0
ENGINEERING AND OPERATING COMMITTEE:

19.1    The 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.
19.2    The 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.
19.3    The Engineering and Operating Committee shall have the following
functions and responsibilities:
19.3.1    Review and approve the following items related to the performance of
Operating Work.
19.3.1.1    Capital Improvements and the annual Capital Improvements budget.
19.3.1.2    The annual staffing table.
19.3.1.3    The annual operation and maintenance budget.

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19.3.1.4    Such written statements of operating or maintenance procedures as
may be submitted to the Engineering and Operating Committee.
19.3.1.5    The planned annual maintenance schedule.
19.3.1.6    The policies for establishing the Emergency Spare Parts inventory.
19.3.1.7    The policies for establishing the inventory for Materials and
Supplies.
19.3.1.8    The 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).
19.3.1.9    The 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.
19.3.1.10    The principles and procedures for establishing communication
channels among Participants.
19.3.1.11    The operating procedures for performance and efficiency testing.
19.3.1.12    The operating procedures for maintaining complete and accurate
Capacity and Energy accounting.

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19.3.1.13    The Operating Agent’s estimate and analysis of the total
expenditures resulting from an Operating Emergency, as provided in Section 29.7.
19.3.1.14    The results and expenditures of programs and contracts on
environmental control and data collection for which the Operating Agent has
contracted.
19.3.2    Establish 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.
19.3.3    Except for an Operating Emergency, as provided in Section 29,
designate a construction agent responsible for the design, construction and
acquisition of Capital Improvements.
19.3.4    Approve the list of transportation and motorized equipment to be
purchased or leased by the Operating Agent for use in the performance of
Operating Work.
19.3.5    Perform such other functions and responsibilities as may be assigned
to it from time to time by the Coordination Committee.
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

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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.
19.5    The 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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19.6    In 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.
19.7    In 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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20.0
FUELS COMMITTEE:

20.1    As 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. The Fuels Committee shall have no authority to
modify any of the provisions of this Agreement.
20.2    The 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 the Participant that is a signatory to the CSA. 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.
20.3    Subject to Section 20.7, the Fuels Committee shall have the following
functions and responsibilities:
20.3.1    To conduct studies, or cause studies to be conducted, regarding
criteria pertaining to the acquisition of coal supplies and the negotiation and

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approval of coal agreements. Such studies and recommendations may include, but
are not limited to:
20.3.1.1    Annual fuel supply budgets
20.3.1.2    Coal cost
20.3.1.3    Coal delivery rates and minimum take obligations
20.3.1.4    Coal quality
20.3.1.5    Contract terms
20.3.1.6    Economic requirements
20.3.1.7    Negotiation strategies
20.3.1.8    Potential 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 the
study. Nothing in this Section 20.3 shall be construed to require the Operating
Agent or any Participant to undertake any uncompensated or unfunded study which
it would not otherwise perform.
20.3.2    To 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.
20.3.3    To 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.

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20.3.4    To provide regular progress reports to the Engineering and Operating
and to the Coordination Committees, as requested by such committees.
20.3.5    To establish the amount of coal to be maintained in the Emergency Coal
Storage Pile.
20.3.6    To establish operating procedures for delivery of coal to the
Emergency Coal Storage Pile.
20.3.7    To establish procedures for the determination of Participant Coal
Consumption.
20.3.8    To perform such other functions and responsibilities as may be
assigned to it from time to time by the Coordination Committee.
20.4    The following special procedures shall apply to all negotiations or
discussions with SJCC regarding amendment, interim pricing agreements,
termination or succession of the CSA, 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 Participant which is a signatory to the CSA,
in the conduct of its day-to-day operational responsibilities, from performing
Operating Work, engaging in business contacts and communications with SJCC or
other coal suppliers or potential suppliers to the San Juan Project or in the
administration of the CSA and related agreements.
20.4.1    The Participant which is a signatory to the CSA shall be entitled to
have at least two (2) representatives present at any such negotiations or
discussions.

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Participants not signatories to the CSA or its successors shall have the
collective right to have two (2) representatives present at any such
negotiations or discussions. The non-signatory Participants may jointly or
separately designate representatives, but in no case may the total number of
representatives so designated by all of the non-signatory Participants exceed
two (2). Any dispute among the non-signatory 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 designated in
writing by the Participant which is a signatory to the CSA and non-signatory
Participants. If such representatives are not employees of a non-signatory
Participant, such fact shall be disclosed in writing to all 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
Participant that is a signatory to the CSA, such approval not to be unreasonably
withheld. Such confidentiality agreements shall be executed by a non-signatory
Participant’s Coordination Committee representative or, as appropriate, the
person authorized by such non-signatory Participant or Representative to execute
such documents. Representatives may be changed by non-signatory Participants by
the giving of written notice to all other Participants.

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20.4.2    Representatives 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.
20.5    Any proposed action or determination regarding any amendment of the CSA,
replacement of the CSA with a new agreement or any interim or other annual coal
pricing agreement related to the CSA (or its successor) or any other action or
determination of the Fuels Committee shall be submitted to the vote of the
representatives 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.
20.5.1    If, upon such vote, the requisite votes are obtained, the Participant
which is a signatory to the CSA 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.
20.5.2    If, 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 18.4.3. If the requisite majorities are
obtained in the Coordination Committee vote, the Participant which is a
signatory to the CSA 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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20.5.3    If the requisite votes are not obtained in the Coordination Committee
vote, then consistent with Section 18.7, the Participant which is a signatory to
the CSA 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.
20.6    The 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.
20.7    Nothing in this Section 20 is intended to affect the responsibilities of
the Reclamation Oversight Committee or the Reclamation Trust Funds Operating
Agent as set out in the Mine Reclamation Agreement; in particular, the Fuels
Committee shall have no authority to vote as to matters related to amendments to
provisions of the RSA or a new agreement for the performance of reclamation
services for disturbance of the SJCC Site Area. To the extent of any conflict
between this Section 20 and the Mine Reclamation Agreement, the provisions of
the Mine Reclamation Agreement shall control.

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21.0
AUDITING COMMITTEE:

21.1    The 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.
21.3    The Auditing Committee shall have the following functions and
responsibilities under this Agreement:
21.3.1    Review 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.
21.3.2    Review 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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21.3.3    Certify 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.
21.3.4    Review 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.
21.3.5    Review and approve the Operating Agent’s cost and expense allocations
between (i) electric generation and related functions and (ii) unrelated
functions.
21.3.6    Advise and make recommendations to the Coordination Committee and
Operating Agent on matters involving auditing and financial transactions.
21.3.7    Develop procedures for proper accounting and financial liaison between
Participants in connection with the Operating Work and Capital Improvements.
21.3.8    Perform 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.
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

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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.
21.5    The 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.
21.6    In 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.
21.7    In 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

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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.
21.8    To the extent practicable, any audit of A&G expenses will be coordinated
with audits of A&G expenses under any other San Juan Project-related agreements,
including audits of reclamation A&G expenses.

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PART V
BUDGETS AND OPERATING EXPENSES
22.0
OPERATION AND MAINTENANCE EXPENSES:

22.1    The 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:
22.1.1    For Unit 1 and for all equipment and facilities directly related to
Unit 1 only, in accordance with the following percentages:
22.1.1.1    PNM - 50 percent
22.1.1.2    TEP - 50 percent
22.1.1.3    [Omitted]
22.1.1.4    Farmington - 0 percent
22.1.1.5    [Omitted]
22.1.1.6    LAC - 0 percent
22.1.1.7    [Omitted]
22.1.1.8    [Omitted]
22.1.1.9    UAMPS - 0 percent

22.1.2    [Omitted]
22.1.3    For Unit 4 and for all equipment and facilities directly related to
Unit 4 only, in accordance with the following percentages:
22.1.3.1    PNM - 77.297 percent
22.1.3.2    TEP - 0 percent
22.1.3.3    [Omitted]
22.1.3.4    Farmington - 8.475 percent
22.1.3.5    [Omitted]
22.1.3.6    LAC - 7.20 percent
22.1.3.7    [Omitted]
22.1.3.8    [Omitted]
22.1.3.9    UAMPS - 7.028 percent

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

22.1.4.1    PNM - 50 percent
22.1.4.2    TEP - 50 percent
22.1.4.3    [Omitted]
22.1.4.4    Farmington - 0 percent
22.1.4.5    [Omitted]
22.1.4.6    LAC - 0 percent
22.1.4.7    [Omitted]
22.1.4.8    [Omitted]
22.1.4.9    UAMPS - 0 percent

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

22.1.5.1    PNM - 77.297 percent
22.1.5.2    TEP - 0 percent
22.1.5.3    [Omitted]
22.1.5.4    Farmington - 8.475 percent
22.1.5.5    [Omitted]
22.1.5.6    LAC - 7.20 percent
22.1.5.7    [Omitted]
22.1.5.8    [Omitted]
22.1.5.9    UAMPS - 7.028 percent

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

22.1.6.1    PNM - 65 percent
22.1.6.2    TEP - 35 percent
22.1.6.3    [Omitted]
22.1.6.4    Farmington - 0 percent
22.1.6.5    [Omitted]
22.1.6.6    LAC - 0 percent
22.1.6.7    [Omitted]
22.1.6.8    [Omitted]
22.1.6.9    UAMPS - 0 percent

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22.1.7    Except 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
and any O&M under Section 4.2.2 of the Decommissioning Agreement, in accordance
with the following percentages through June 30, 2022:

22.1.7.1    PNM - 70.381 percent
22.1.7.2    TEP - 19.8 percent
22.1.7.3    [Omitted]
22.1.7.4    Farmington - 3.679 percent
22.1.7.5    [Omitted]
22.1.7.6    LAC - 3.123 percent
22.1.7.7    [Omitted]
22.1.7.8    [Omitted]
22.1.7.9    UAMPS - 3.017 percent
If the term of this Agreement is extended beyond June 30, 2022, then the
percentages shown in Section 6.2.6 (as modified by any transfers pursuant to
Sections 40A or 40B) shall apply after June 30, 2022 in lieu of the percentages
set forth in this Section 22.1.7.
22.1.8    In the event of a permanent shutdown of Unit 1 prior to the permanent
shutdown of Unit 4, 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 4
prior to the permanent shutdown of Unit 1, 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. Expenses incurred under this Section 22.1.8 shall
be minimized insofar as reasonably practicable, and any expenses paid

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by a Participant under this Section 22.1.8 that would otherwise qualify as costs
of initial or interim Decommissioning Work under Sections 4.1 and 4.2 of the
Decommissioning Agreement shall be credited against the Participants’ cost
responsibilities under the Decommissioning Agreement.
22.1.9    Exhibit 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.

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22.2    O&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:
22.2.1    Power 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.
22.2.2    Administrative 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.
22.2.3    O&M Expenses chargeable to FERC Account 501 shall be apportioned among
the Participants in accordance with Section 23.
22.2.4    The 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

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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.
22.3    Power 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.
22.4    The 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.
22.5    The 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.
22.6    Payroll 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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22.6.1    If 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.
22.6.2    The 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.
22.6.3    If 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

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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.
22.6.4    Any 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.
22.7    As 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.
22.8    At 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.
22.9    The 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

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other employees and agents of the Operating Agent) in performing tasks requested
by 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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23.0
FUEL COSTS

23.1    The quantity of coal delivered to the San Juan Project shall be
determined by the belt scales, in accordance with the CSA.
23.2    The Operating Agent shall maintain the Project Coal Inventory wherein
ownership shall be apportioned among the Participants in the percentages shown
in Section 6.3. Coal inventory shall be accounted for in FERC Account 151.
23.3    [Omitted]
23.4    [Omitted]
23.5    Limestone 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.
23.6    All 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:
23.6.1    Variable 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.
23.6.2    Fixed fuel-related expenses (including, but not limited to fuel
handling) on the basis of Common Participation Share.
23.6.3    Fuel 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 Unit 1 and Tank 3
and 4 storage tank feeds Unit 4. When oil is withdrawn from a storage tank for

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consumption, it is metered by Unit. Costs for fuel oil usage shall be separately
accounted for by these two storage tanks as follows:
23.6.3.1    Costs 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
Unit 1 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
Unit 1 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 Unit 1 Participants on the basis of Section 6.2.4.
23.6.3.2    Costs 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
Unit 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

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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 Unit 4 Participants first on the
basis of the individual Unit metered consumption and then on the basis of
Section 6.2.3. The cost for fuel oil withdrawn from Tank 3 and 4 thusly credited
to FERC Account 151 shall be apportioned among the Unit 4 Participants on the
basis of Section 6.2.5.
23.7    The 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    [Omitted]
23.7.2    [Omitted]
23.7.3    Total actual coal deliveries by SJCC to the San Juan Project for each
month and for the year to date.
23.7.4    Total actual coal deliveries to the San Juan Project for each month
and for the year to date, allocated to the Participants.
23.7.5    Total cost and tonnage of inventory allocated to the Participants.
23.8    The Operating Agent shall work diligently with SJCC under the terms of
the CSA 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.

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23.9    In the event that SJCC defaults in its obligations under the CSA 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 CSA or may procure, subject to the CSA, an alternate coal
supply.
23.10    The 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.
23.11    In 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 CSA, 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 shall remain frozen until such time as such Unit 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 Unit. 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.
23.12    The 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

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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.
23.13    Any 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 Units 1 and 4 until
classified by the Coordination Committee.
23.14    Beginning on January 1, 2018, PNM will supply coal to the Participants
under the provisions of Section 23.18.
23.15    [Omitted]
23.16    [Omitted]
23.17    [Omitted]
23.18    SJCC will invoice PNM monthly as provided under the CSA. PNM will
invoice each Participant monthly by Coal Tonnage Component and such Coal Tonnage
Component will be paid for as follows:
23.18.1    Pre-existing Stockpile Coal tons as invoiced by SJCC will be
allocated by a Participant’s Common Participation Share as of the effective date
of the Restructuring Agreement and will be paid for by each Participant at the
price per ton charged by SJCC in its monthly invoicing to PNM.
23.18.2    Each year, PNM will develop a monthly Tier 1 Tonnage Allocation
schedule with SJCC in the annual operating plan process as provided for in
Section

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7.2 of the CSA. With input from the Participants, PNM will develop a monthly
allocation by Participant of such Tier 1 Tons (such individual allocation, its
“Tier 1 Tonnage Allocation”). Such monthly Tier 1 Tonnage Allocation will be
paid for by Participants whether or not their Participant Coal Consumption
exceeded their Tier 1 Tonnage Allocation in the month. Monthly, for each
Participant, its Tier 1 Tonnage Allocation, net of its invoiced Pre-existing
Stockpile Coal for such month will be paid for at the then existing price for
Tier 1 Tons under the CSA. In each of 2018 and 2019, two million eight hundred
thousand (2,800,000) tons will be allocated by Participant Share. In each of
2020 and 2021, two million eight hundred thousand (2,800,000) tons will be
allocated by Participant Share, and then PNM’s allocation will be reduced by one
hundred fifty thousand (150,000) tons in each of those years. In 2022, one
million four hundred thousand (1,400,000) tons will be allocated by Participant
Share.
23.18.3    To the extent that a Participant’s Participant Coal Consumption in a
month exceeds its Tier 1 Tonnage Allocation for such month, PNM will invoice
such Participant such excess as Tier 2 Tons to be paid for at the then existing
price for Tier 2 Tons under the CSA.
23.18.4    Legacy Costs as invoiced monthly by SJCC will be allocated using a
Participant’s Common Participation Share for that year.
23.18.5    Cost for SJCC’s reclamation bond premium invoiced through the CSA
will be allocated using a Participant’s Common Participation Share for that
year.

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23.18.6    Weight-based taxes will be applied to the tonnages as invoiced by PNM
to each Participant at the then-existing rates applicable to SJCC invoices.
23.18.7    Revenue-based taxes and royalties will be applied to the tonnages and
total coal costs as invoiced by PNM to each Participant at the then-existing
rates applicable to SJCC invoices.
23.18.8    In the event of an SJCC environmental force majeure, then Available
Pre-existing Stockpile Tons will be allocated in the same manner as Pre-existing
Stockpile Coal tons, and Force Majeure Tons will be allocated in the same manner
as Tier 1 Tons unless otherwise approved by the Participants in the Fuels
Committee. Such calculations will be on an annual basis.
23.18.9    Any other costs billed by SJCC under the CSA and not specifically
addressed in this Section 23.18 will be apportioned among and paid for by the
Participants on the basis of the Participant’s Common Participation Share for
that year unless otherwise annually approved by the Participants in the Fuels
Committee.
23.18.10 Annual Year-End Reconciliation Process.    
23.18.10.1    At the end of each year, the Operating Agent will reconcile the
sum of each Participant’s monthly CSA-related payments to a properly allocable
share of annual Tier 1 Tons, Tier 2 Tons, Pre-existing Stockpile Coal tons, and
cost associated with any change in Project Coal Inventory and invoice or refund
any such reconciliation amounts to each Participant.
23.18.10.2    Any net consumption of Project Coal Inventory tons will be charged
to FERC Account 501 and apportioned among and paid for

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by the Participants on the basis of the percentage that each Participant’s
annual Tier 2 Tons after the reconciliation process bears to the total annual
Tier 2 Tons consumption after the reconciliation process for all Units. The
price for such tons will 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 will subsequently be credited to FERC
Account 151 and apportioned to the Participants based on the Participant’s
Common Participation Share for that year.
23.18.10.3    The costs of any net addition to Project Coal Inventory tons, as
invoiced by SJCC, will be charged to FERC Account 151 and apportioned to and
paid for by the Participants based on the Participant’s Common Participation
Share for that year.
23.18.10.4    If, at the end of any year, the Operating Agent has collected
amounts in excess of those due SJCC under the CSA, such over-collection will be
refunded to the Participants. The refund to each Participant will 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 Tier 1 Tonnage
Allocation divided by the total amount by which all such Participants’ Coal
Consumption was less than their Tier 1 Tonnage Allocation.

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23.19    The cost of evaluating a long-term fuel supply for the San Juan
Project, approved pursuant to a resolution of the Coordination Committee of May
23, 2014, shall be shared among the Participants in accordance with the
following percentages:
23.19.1    PNM - 70.381 percent
23.19.2    TEP - 19.8 percent
23.19.3    Farmington - 3.679 percent
23.19.4    LAC - 3.123 percent
23.19.5    UAMPS - 3.017 percent

To the extent that the cost of evaluating a long-term fuel supply for the San
Juan Project has been invoiced and paid at a different percentage allocation
than that set forth immediately above, the Participants agree to a true-up of
the over- or under-payment to these percentages as of the effective date of the
Restructuring Agreement.

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24.0
ANNUAL BUDGETS:

24.1    Not 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.
24.2    The 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.
24.3    Any 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.
24.4    The 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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25.0
PAYMENT OF TAXES:

25.1    The 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.
25.2    All 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.
25.3    If 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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26.0
MATERIALS AND SUPPLIES:

26.1    The 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.
26.2    The 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.
26.3    The 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.
26.4     Materials 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.
26.5    Materials 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.
26.6    Materials 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

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available terms. The proceeds, if any, received shall be credited or distributed
to the Participants in the same proportion as their Participation Shares
therein.
26.7    A 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.
26.8    The 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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27.0
EMERGENCY SPARE PARTS:

27.1    The 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.
27.2    The 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.
27.3    Emergency Spare Parts shall be owned by and the costs thereof shall be
allocated between the Participants in accordance with their respective
Participation Shares.
27.4    The 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
28.0
OPERATION AND MAINTENANCE:

28.1    PNM is the Operating Agent, unless replaced in accordance with Section
33.
28.2    All 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.
28.3    Subject to the provisions, conditions, limitations and restrictions of
this Agreement, the Operating Agent shall:
28.3.1    Perform the Operating Work in accordance with the Project Agreements
and Prudent Utility Practice.
28.3.2    Contract for, furnish or obtain the services and studies necessary for
performance of Operating Work.
28.3.3    Arrange for the placement and maintenance of Operating Insurance.
28.3.4    Execute 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.
28.3.5    Furnish and train the necessary personnel for performance of Operating
Work.
28.3.6    Have 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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28.3.7    Enforce and comply with all contracts entered into for the performance
of Operating Work.
28.3.8    Comply with any and all laws and regulations applicable to the
performance of Operating Work.
28.3.9    Maintain 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 CSA and the CCRDA.
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

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Operating Work and furnish the Participants with copies of any notices given or
received pursuant to the Project Agreements.
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

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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).
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.
28.3.27    In the event of the failure of the Participant which is a signatory
to the CSA then in effect to reach agreement on a matter described in Sections
18.7

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and 20.5.3, maintain a supply of coal to the San Juan Project, consistent with
Prudent Utility Practice.
28.3.28    Manage the activities of the “designated representative” pursuant to
the DR Agreement.
28.3.29    Perform all of the duties and obligations set out in this Agreement
as duties and obligations of the Operating Agent.
28.4    The 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.
28.5    The 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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29.0
OPERATING EMERGENCY:

29.1    In 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.
29.2    As 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.
29.3    In 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.
29.4    In 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.
29.4.2    The person or persons who would perform the work and furnish the
materials required to terminate the Operating Emergency.

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29.4.3    The estimated amount of overtime, if any, which would be necessary in
order to expedite the termination of the Operating Emergency.
29.4.4    The costs that are proposed to be capitalized, and salvage realized.
29.4.5    The costs that are proposed to be charged as maintenance expense.
29.4.6    The proposed administrative and general expense allowance applicable
to such repair or reconstruction.
29.4.7    Such 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.
29.5    The Engineering and Operating Committee shall review and approve the
proposed repair or reconstruction, including the estimated cost thereof or shall
agree upon an alternative.
29.6    Costs 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.
29.7    Following 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.
29.8    The 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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30.0
PAYMENT OF EXPENSES BY PARTICIPANTS:

30.1    All 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.
30.2    The 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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30.3    Each 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:
30.3.1    Expenses described in Sections 30 and 22 shall be billed in writing as
follows:
30.3.1.1    The payroll costs to be paid to the Operating Agent’s employees for
each pay period.
30.3.1.2    On 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.
30.3.2    Bills submitted under Section 30.3.1 shall be due and payable within
seven (7) business days following receipt of the bill.
30.3.3    Expenses 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.
30.3.4    Expenses 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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30.4    Except 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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31.0
OPERATING INSURANCE:

31.1    Unless 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:
31.1.1    Risks 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).
31.1.2    Risks 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.
31.1.3    Risks 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.
31.1.4    Risks 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.
31.2    Except 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

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Participation Share as established in Section 6. Operating Insurance referred to
in Section 31.1.1 shall carry cross-liability coverage.
31.3    In 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.
31.4    The 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.
31.4.1    Any deductibles shall be shared by the Participants in accordance with
the percentages established in Section 22.1.
31.5    The 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.
31.6    Each 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.

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31.7    Operating 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.
31.8    Nothing 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.
31.9    If 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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31.10    In 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.
31.11    Each 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.
31.12    On 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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32.0
SURPLUS OR RETIRED PROPERTY:

The Operating Agent shall dispose of surplus property of an operating Unit or
property no longer used or useful in the operation of such a Unit 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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33.0
REMOVAL OF OPERATING AGENT:

33.1    The 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.
33.2    The Operating Agent may be removed as Operating Agent for any one of the
following reasons:
33.2.1    The 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
Operating Agent. If, pursuant to this Section 33.2.1, the Coordination Committee

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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.
33.2.2    If, 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.
33.2.3    Notwithstanding 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.
33.3    Prior 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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34.0
DEFAULTS BY OPERATING AGENT:

34.1    The 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:
34.1.1    In 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.
34.1.2    If 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.
34.1.3    The 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
35.0
DEFAULTS:

35.1    Each 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. A default under the Mine Reclamation Agreement or
the Decommissioning Agreement is not a default under this Agreement. If a
Participant breaches a performance obligation under Section 5 of the
Restructuring Agreement, which provisions are incorporated in Section 23 of this
Agreement, the non-defaulting Participants’ remedies shall be as provided in
this Agreement. A default under any other section of the Restructuring Agreement
shall not be a default under this Agreement, irrespective of whether it is
incorporated in this Agreement, and remedies for such a default shall be as
provided in the Restructuring Agreement.
35.2    In 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:
35.2.1    The 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.
35.2.2    The notice of default shall specify the existence, nature and extent
of the default. Upon receipt of the notice of default, the defaulting
Participant shall

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immediately take all steps necessary to cure the default as promptly and
completely as possible.
35.3    In 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 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.
35.4     In 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:

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35.4.1    If 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 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.
35.4.2    Within 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

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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:
35.4.2.1    A 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;
35.4.2.2    Billing and accounting of such costs;
35.4.2.3    Dispatch and scheduling of the defaulting Participant’s
proportionate share of Net Effective Generating Capacity; and
35.4.2.4    Any other items required for the optimal use of the San Juan Project
and the mitigation of damages by the non-defaulting Participants.
35.4.2.5    If 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.
35.4.3    Within 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

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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 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.
35.4.4    A 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.
35.5        During 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)

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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.
35.6    In 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.
35.7    The 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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35.8    No 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.
35.9    The 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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36.0
LIABILITY:

36.1    Except 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.
36.1.1    In the event any insurer providing insurance refuses to pay any
judgment obtained by a Participant against any other Participant, 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 consideration 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 Participant the opportunity to enforce its judgment
directly against such insurer. In

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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.
36.1.2    To 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.
36.1.3    Each 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.
36.2    Except 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 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,

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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
Participant, 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
Agreements.
36.3     If 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.
36.4    Except 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 harmless 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.
36.5     Each 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

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directors, members of their governing bodies, officers and employees, from any
such damage, loss, claim, cost, charge or expense.
36.6    Except 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:
36.6.1    All such liability for damages, losses, claims, costs, charges or
expenses of such Participant shall not exceed fourteen million dollars
($14,000,000) 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 fourteen
million dollars ($14,000,000) per occurrence.
36.6.2    A 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 fourteen million
dollar ($14,000,000) 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
Section 36.6.2(i) shall be entitled to participate in any remaining portion of
the fourteen

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million dollar ($14,000,000) 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 Participants’ unsatisfied judgments or settlements.
36.7    The 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.
36.8    If 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.
36.9    The Participants agree that the aggregate liability limit of fourteen
million dollars ($14,000,000) 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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37.0
ARBITRATION:

37.1    If 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 the performance or nonperformance of any obligation
under this Agreement, 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). Disputes arising under the Mine Reclamation Agreement and the
Decommissioning Agreement shall be resolved pursuant to the dispute resolution
provisions of those agreements. Disputes arising under Section 5 of the
Restructuring Agreement, to the extent such provisions are incorporated in
Section 23 of this Agreement, shall be resolved pursuant to the dispute
resolution provisions of this Agreement. Any other disputes arising under the
Restructuring Agreement shall be resolved pursuant to the dispute resolution
provisions of the Restructuring Agreement.
37.2    The 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.

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37.3    Within 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) 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.
37.4    Except 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

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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.
37.5    Included 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.
37.6     The 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 Participant
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.
37.7     This 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.
37.8     Each 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

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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.
37.9     In 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.

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PART VIII
RETIREMENT AND RECONSTRUCTION
38.0
DESTRUCTION, DAMAGE OR CONDEMNATION OF A UNIT:

38.1    If 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. The
retirement of Units 2 and 3 shall not be within the scope of this Section 38.
38.2     Failure 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. Disposal of the facilities not
destroyed, damaged or condemned shall be considered interim Decommissioning Work
under Section 4.2 of the Decommissioning Agreement and the net proceeds from
such disposal shall be distributed in accordance with the relevant provisions of
the Decommissioning Agreement. 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.

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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. This Section 38.3
is subject to the operation of Section 40A.
38.4     In 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. This Section
38.4 is subject to the operation of Section 40A.

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39.0
RIGHTS OF PARTICIPANTS UPON TERMINATION:

39.1    In the event the Participants by unanimous agreement abandon, retire or
otherwise terminate operation of the San Juan Project prior to the termination
of this Agreement, the facilities forming the San Juan Project shall be disposed
of or otherwise addressed in a manner consistent with the Decommissioning
Agreement.

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40.0
DECOMMISSIONING OF THE PROJECT:

40.1    Upon the effective date of the Decommissioning Agreement, the
decommissioning of the San Juan Project shall be governed by the Decommissioning
Agreement.
40.2    If PNM or TEP determines, pursuant to Section 4.3.3 of the
Decommissioning Agreement, to retain and not decommission certain of its solely
owned facilities or property of the San Juan Project, such designating party
will be responsible for decommissioning costs associated with such facilities or
property. With respect to facilities or property of the San Juan Project jointly
owned by PNM and TEP, any designation pursuant to Section 4.3.3 of the
Decommissioning Agreement shall be made jointly by PNM and TEP, and both parties
will be responsible for decommissioning costs associated with such facilities or
property.

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40A.0    EXTENSION OF TERMINATION DATE FOR LARGE CAPITAL IMPROVEMENT:

40A.1        If the Coordination Committee votes on a CBI for a Large Capital
Improvement as provided for in Section 18.4.4, and unanimously approves the
Large Capital Improvement, then the project shall be performed and the
Participants shall extend the term of this Agreement, if appropriate.
40A.2        If the Coordination Committee votes on a CBI for a Large Capital
Improvement as provided for in Section 18.4.4, and does not unanimously approve
the Large Capital Improvement, then the Participant(s) that voted against the
Large Capital Improvement (each a “Disapprover”) shall have the right to
negotiate with third parties or other Participants to market their share of the
San Juan Project. PNM will have a right of first refusal to purchase any
Disapprover’s interest in the San Juan Project as set forth in Section 11. If no
third party or other Participant has agreed to purchase the Disapprover’s
interest within three (3) months of the date of the CBI vote as evidenced by a
binding agreement, then the Disapprover and the Participants that voted in favor
of the Large Capital Improvement (each an “Approver”) shall negotiate in good
faith for the conveyance of the Disapprover’s rights, titles and interests in
the San Juan Project to other Participants, or other equitable option, in a
manner consistent with this Agreement that assures the continued successful and
proper operation and maintenance of the San Juan Project; provided, however,
that no Approver is under any obligation to acquire the rights, titles and
interests of the Disapprover. The Approver’s acquisition price for the
Disapprover’s ownership interest shall be zero. No Participant shall
unreasonably fail to

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grant any requisite approval to a sale or transfer by a Disapprover under this
Section 40A.2.
40A.3        If the Participants cannot agree on a Disapprover’s sale or
transfer of its respective rights titles and interests in the San Juan Project,
or other equitable option, then the Disapprover shall retain its existing
ownership interest in the San Juan Project and the Large Capital Improvement
shall not be made.
40A.4        Any agreement pursuant to Section 40A.2 between a Disapprover and
any Approver that acquires the Disapprover’s right, title and interest in the
San Juan Project shall include the following provisions: (i) in the event TEP is
a Disapprover, TEP shall transfer its water rights and San Juan Project land to
PNM (but not ownership and rights in the Switchyard) when it transfers its other
rights, titles and interests in the San Juan Project; (ii) the Disapprover shall
continue to pay SJCC for coal pursuant to the then-current CSA through the date
of transfer; (iii) the Disapprover shall continue to pay SJCC for CCR disposal
pursuant to the then-current CCRDA through the date of transfer; (iv) the
Disapprover shall not be responsible for any costs associated with any new or
future extension of coal supply or CCRDA services; (v) the Approver shall
purchase the coal inventory and fuel oil of the Disapprover at book value on the
date of transfer; (vi) subject to the terms of the Mine Reclamation Agreement,
the Participants shall negotiate in good faith to address the allocation of post
-2017 reclamation liability between the Approvers and Disapprover; (vii) the
Disapprover may elect its status as an Opt-in or Opt-out Participant to the
extent provided in the Mine Reclamation Agreement; (viii) the responsibility of
the Disapprover and the Approvers for Capital Improvements arising before the
transfer shall be addressed; (ix) the Disapprover shall retain its transmission

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rights; (x) voting rights shall be adjusted to reflect the exit of the
Disapprover and allow the Approvers to approve the Large Capital Improvement;
(xi) an environmental baseline study shall be performed under terms agreed by
the Approver and Disapprover and indemnification provided to the Disapprover for
environmental liabilities arising after the date of transfer of the
Disapprover’s rights, titles and interests in the San Juan Project, in a manner
similar to the Restructuring Agreement; (xii) the Disapprover’s removal from
this Agreement; and (xiii) subject to Section 43.9, after the date of transfer,
Disapprovers are only responsible for costs and other obligations and
liabilities arising under the Restructuring Agreement, the Mine Reclamation
Agreement and the Decommissioning Agreement.

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40B.0    EXTENSION OF TERMINATION DATE AND COAL SUPPLY AGREEMENT:
40B.1 No later than June 30, 2018, the Operating Agent shall have negotiated
prices for coal for the San Juan Project, beginning July 1, 2022 for a time
period and volume agreed upon by the Participants. Based upon pricing and other
relevant information, the Participants shall provide notification in writing
whether they wish to extend the CSA and the term of this Agreement beyond July
1, 2022 (each an “Extender”) or do not wish to do so (“Non-Extender”).
40B.2     If all Participants are Extenders, then the Participants shall
negotiate a binding extension of the CSA and shall extend this Agreement for an
appropriate term beyond July 1, 2022. If all Participants are Non-Extenders,
then this Agreement shall terminate on July 1, 2022, and the Participants shall
plan for an orderly closure of the San Juan Project in 2022.
40B.3    If one or more of the Participants are Non-Extenders, such
Non-Extenders shall have the right to negotiate with third parties or Extenders
to market their interest in the San Juan Project. The Non-Extender may sell its
ownership interest in the Project to a third party or Extender and must have
entered into a binding agreement by November 15, 2018. PNM shall have a right of
first refusal to purchase any Non-Extenders’ interest in the San Juan Project as
set forth in Section 11. If, by November 15, 2018, no third party or Extender
has agreed to purchase the Non-Extenders’ interest in the San Juan Project, the
Non -Extenders shall negotiate in good faith with the Extenders to convey the
Non-Extenders’ rights, titles and interests in the San Juan Project to the
Extenders in a manner that is consistent with this Agreement and assures the
continued successful and proper operation and maintenance of the San Juan
Project. The Extender’s acquisition

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price for the Non-Extenders’ ownership interests shall be zero. No Participant
shall unreasonably fail to grant any requisite approval to a sale or transfer by
a Non-Extender under this Section 40B.3. In the event the Extenders and
Non-Extenders cannot reach agreement on the conveyance of such ownership
interests, they shall plan for an orderly closure of the San Juan Project in
2022.
40B.4    Any agreement pursuant to Section 40B.3 between a Non-Extender and the
Extender that acquires the Non-Extender’s right, title and interest in the San
Juan Project shall include the following provisions: (i) in the event TEP is a
Non-Extender, TEP shall transfer its water rights and San Juan Project land to
PNM (but not ownership and rights in the Switchyard) when it transfers its other
rights, titles and interests in the San Juan Project; (ii) the Non-Extenders
shall continue to pay SJCC for coal pursuant to the then-current CSA through the
date of the transfer; (iii) the Non-Extenders shall continue to pay SJCC for CCR
disposal pursuant to the then-current CCRDA through the date of the transfer;
(iv) the Non-Extenders shall not be responsible for any costs associated with
post-2022 coal supply or CCRDA services; (v) the Extender shall purchase coal
inventory and fuel oil of the Non-Extenders at book value on the date of
transfer; (vi) subject to the terms of the Mine Reclamation Agreement, the
Participants shall negotiate in good faith to address the allocation of
post-2017 reclamation liability between Extenders and Non-Extenders; (vii) any
Non-Extender may elect its status as an Opt-in or Opt-out Participant to the
extent provided in the Mine Reclamation Agreement; (viii) the Non-Extenders will
not be responsible for any Capital Improvements after November 15, 2018, that
extend the life of the San Juan Project beyond June 30, 2022; (ix) the
Non-Extenders will retain their transmission rights; (x) voting rights will be
adjusted to reflect the exit of the Non-

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Extenders; (xi) an environmental baseline study shall be performed under terms
agreed by the Extender and Non-Extender and indemnification provided to the
Non-Extender for environmental liabilities arising after June 30, 2022, in a
manner similar to the Restructuring Agreement; (xii) the Non-Extender’s removal
from this Agreement; and (xiii) subject to Section 43.9, after the date of
transfer, Non-Extenders are only responsible for costs and other obligations and
liabilities arising under the Restructuring Agreement, the Mine Reclamation
Agreement and the Decommissioning Agreement.

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PART IX
MISCELLANEOUS PROVISIONS
41.0
RELATIONSHIP OF PARTICIPANTS:

41.1    The 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 Participants. 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 without its express
written consent, except as expressly provided herein.
41.2    The 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 Participants hereunder.

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42.0
NOTICES:

42.1    Any 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
electronic mail during regular business hours or the day after transmission, if
sent after regular business hours (provided however, that such facsimile or
electronic mail 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:

42.1.1    Public Service Company of New Mexico
Attn: Vice President, PNM Utility Operations
414 Silver Ave. SW
Albuquerque, NM 87102

With a copy to:

Public Service Company of New Mexico
c/o Secretary
414 Silver Ave. SW
Albuquerque, New Mexico 87102

42.1.2    Tucson Electric Power Company
88 E. Broadway Blvd.
MS HQE901
Tucson, Arizona 85701
Attn: Corporate Secretary

42.1.3    City of Farmington
c/o City Clerk
800 Municipal Drive
Farmington, NM 87401

With a copy to:

        

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Farmington Electric Utility System
Electric Utility Director
101 North Browning Parkway
Farmington, NM 87401

42.1.4    Incorporated County of
Los Alamos, New Mexico
c/o County Clerk
1000 Central Ave.
Suite 240
Los Alamos, NM 87544

with a copy to:

Incorporated County of
Los Alamos, New Mexico
c/o Utilities Manager
1000 Central Ave.
Suite 130
Los Alamos, NM 87544

42.1.5    Utah Associated Municipal Power Systems
c/o General Manager
155 North 400 West
Suite 480
Salt Lake City, UT 84103

42.2    A 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.
42.3    The 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.

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43.0
OTHER PROVISIONS:

43.1    Each 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.
43.2    No 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 or terrorism, 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.
43.3    The 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.
43.4    This Agreement is made under and shall be governed by the laws of the
State of New Mexico, without regard to conflicts of law principles.

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43.5    The 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.
43.6    In 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.
43.7    All 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.
43.8    Should 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

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adjustment shall be fair and equitable as to both the Operating Agent and the
other Participants.
43.9    The 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 such obligation to pay money or take other
actions in accordance with the Original San Juan PPA, the Amended and Restated
San Juan PPA, the Restructuring Amendment Amending and Restating the Amended and
Restated San Juan PPA, the UG-CSA, the Co-Tenancy Agreement, the Operating
Agreement, the Restructuring Agreement, the Decommissioning Agreement, the Mine
Reclamation Agreement or any other San Juan Project-related agreement.
43.10    Except as provided in Sections 35.1 and 37.1, to the extent of any
conflict between this Agreement and the Restructuring Agreement, the provisions
of the Restructuring Agreement shall control.
43.11    This Agreement terminates and supersedes the Original Exit Date
Amendment.

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44.0
EXECUTION IN COUNTERPARTS:

44.1    This 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.
Electronic or pdf signatures have the same effect as an original signature.

151

--------------------------------------------------------------------------------

45.0
AMENDMENTS:

45.1    Except 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.
45.2    The 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.

152

--------------------------------------------------------------------------------

IN WITNESS WHEREOF, the undersigned parties, by their duly authorized
representatives, have caused this Agreement to be made as of this 1st day of
September, 2017.

Remaining Participants

PUBLIC SERVICE COMPANY
OF NEW MEXICO

                    
By
/s/ Chris Olson            

Its
Vice President                

TUCSON ELECTRIC POWER COMPANY
    

By
/s/ Mark Mansfield            

Its
Vice President, Energy Resources    

THE CITY OF FARMINGTON, NEW MEXICO

By
/s/ Tommy Roberts            

Its
Mayor                    

THE INCORPORATED COUNTY OF LOS ALAMOS,
NEW MEXICO

By
/s/ David Izraelevitz            

Its
Council Chair                

    
UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS

By
/s/ Douglas Hunter            

Its
Chief Executive Officer        

153

--------------------------------------------------------------------------------

Exiting Participants

M-S-R PUBLIC POWER AGENCY

By    /s/ Martin R. Hopper            
Its    General Manager            

SOUTHERN CALIFORNIA PUBLIC POWER
AUTHORITY

By    /s/ Michael S. Webster            
Its    Executive Director            

CITY OF ANAHEIM

By    /s/ Dukku Lee                
Its    Public Utilities General Manager        

TRI-STATE GENERATION AND TRANSMISSION
ASSOCIATION, INC.

By    /s/ Michael S. McInnes        
Its    Chief Executive Officer        

154

--------------------------------------------------------------------------------

PNMR Development and Management Corporation

PNMR DEVELOPMENT AND MANAGEMENT CORPORATION

By    /s/ Elisabeth Eden            
Its    Vice President                

155

--------------------------------------------------------------------------------

STATE OF NEW MEXICO )
)ss.
COUNTY OF BERNALILLO )

The foregoing instrument was acknowledged before me on this 1st day of Sept.,
2017, by Chris Olson, Vice President of Public Service Company of New Mexico, a
New Mexico corporation, on behalf of the corporation.

s/ Juliet Maez            
Notary Public
[SEAL]

My commission expires:

8/29/20        

STATE OF ARIZONA        )
)ss.
COUNTY OF     SANTA CRUZ    )

The foregoing instrument was acknowledged before me on this 23rd day of August,
2017, by Mark Mansfield, VP, Energy Resources, of Tucson Electric Power Company,
an Arizona corporation, on behalf of the corporation.

/s/ Angela Styczykowski    
Notary Public
[SEAL]

My commission expires:

June 25, 2019        

                

156

--------------------------------------------------------------------------------

STATE OF NEW MEXICO    )
)ss.
COUNTY OF SAN JUAN    )

The foregoing instrument was acknowledged before me on this 26th day of July,
2017, by Tommy Roberts, Mayor of The City of Farmington, New Mexico, a New
Mexico municipal corporation, on behalf of the municipal corporation.

/s/ Tamra L. Spencer        
Notary Public
[SEAL]

My commission expires:

August 17, 2020    

                

                

157

--------------------------------------------------------------------------------

STATE OF NEW MEXICO        )
)ss.
COUNTY OF     LOS ALAMOS    )

The foregoing instrument was acknowledged before me on this 27th day of July,
2017, by David Izraelevitz, Council Chair of The Incorporated County of Los
Alamos, New Mexico, a New Mexico Class H County, on behalf of said county.

/s/ Jacqueline D. Salazar    
Notary Public
[SEAL]

My commission expires:

5-24-2021        

                

158

--------------------------------------------------------------------------------

STATE OF UTAH        )
)ss.
COUNTY OF SALT LAKE    )

The foregoing instrument was acknowledged before me on this 1st day of August,
2017, by Douglas Hunter of Utah Associated Municipal Power Systems, a political
subdivision of the State of Utah, on behalf of said entity.

/s/Carolyn Sue Beatty        
Notary Public
[SEAL]

My commission expires:

11-21-2018        
            

159

--------------------------------------------------------------------------------

STATE OF COLORADO    )
)ss.
COUNTY OF     ADAMS    )

The foregoing instrument was acknowledged before me on this 31 day of July,
2017, by Michael S. McInnes, CEO of Tri-State Generation and Transmission
Association, Inc., a Colorado cooperative corporation, on behalf of the said
cooperative corporation.

Penny L. McLaughlin        
Notary Public
[SEAL]

My commission expires:

9/11/2018        

                

STATE OF NEW MEXICO )
)ss.
COUNTY OF BERNALILLO )

The foregoing instrument was acknowledged before me on this 1st day of Sept.,
2017, by Elisabeth Eden, Vice President of PNMR Development and Management
Corporation, a New Mexico corporation, on behalf of the corporation.

/s/ Juliet Maez            
Notary Public
[SEAL]

My commission expires:

8/29/20        

160

--------------------------------------------------------------------------------

CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT                CIVIL CODE § 1189

A notary public or other officer completing this certificate verifies only the
identity of the individual who signed the document to which this certificate is
attached, and not the truthfulness, accuracy, or validity of that document.

State of California            )
County of Amador            )

On August 23, 2017, before me,         Sharon Roethlisberger, Notary
Public            ,        Date                 Here Insert Name and Title of
the Officer    
personally appeared                Martin R. Hopper                    
Name(s) of Signer(s)
______________________________________________________________________________________

who proved to me on the basis of satisfactory evidence to be the person(s) whose
name(s) is/are subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized capacity(ies), and
that by his/her/their signature(s) on the instrument the person(s), or the
entity upon behalf of which the person(s) acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California
that the foregoing paragraph is true and correct.

WITNESS my hand and official seal.

Signature /s/ Sharon Roethlisberger
Signature of Notary Public
[SEAL]

My commission expires Aug. 9, 2018

    Place Notary Seal Above
-----------------------------------------------------------------OPTIONAL----------------------------------------------------------
Though this section is optional, completing this information can deter
alteration of the document or
fraudulent reattachment of this form to an unintended document.

Description of Attached Document
Title or Type of Document:_________________________ Document Date:
_______________
Number of Pages: _______ Signer(s) Other Than Named Above:
______________________________

Capacity(ies) Claimed by Signer(s)

□ Signer's Name:_____________________            □ Signer's
Name:_____________________
□ Corporate Officer ___ Title(s):_________            □ Corporate Officer ___
Title(s):_________
□ Partner -     □ Limited    □ General        □ Partner -     □ Limited    □
General
□ Individual    □ Attorney in Fact            □ Individual    □ Attorney in Fact
□ Trustee    □ Guardian or Conservator            □ Trustee    □ Guardian or
Conservator
□ Other: ____________________________            □ Other:
____________________________
Signer Is Representing: _______________            Signer Is Representing:
_______________
__________________________________            _________________________________

©2014 National Notary Association ·www.NatlonalNotary.org • 1-800-US NOTARY
(1-800-876-6827) Item #5907

161

--------------------------------------------------------------------------------

CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT                CIVIL CODE § 1189

A notary public or other officer completing this certificate verifies only the
identity of the individual who signed the document to which this certificate is
attached, and not the truthfulness, accuracy, or validity of that document.

CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT    
CIVIL CODE § 1189

State of California            )
County of Los Angeles            )

On     August 31, 2017    before me,         Salpi Ortiz, a notary
public            ,
Date                    Here Insert Name and Title of the Officer    
personally appeared                 Michael S. Webster                
Name(s) of Signer(s)
                                                
who proved to me on the basis of satisfactory evidence to be the person(s) whose
name(s) is/are subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized capacity(ies), and
that by his/her/their signature(s) on the instrument the person(s), or the
entity upon behalf of which the person(s) acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California
that the foregoing paragraph is true and correct.

WITNESS my hand and official seal.

Signature    /s/ Salpi Ortiz            
Signature of Notary Public
[SEAL]
My commission expires June 18, 2019

Place Notary Seal Above
-----------------------------------------------------------------OPTIONAL----------------------------------------------------------
Though this section is optional, completing this information can deter
alteration of the document or fraudulent reattachment of this form to an
unintended document.

Description of Attached Document
Title or Type of Document:_________________________ Document Date:
_______________
Number of Pages: _______ Signer(s) Other Than Named Above:
______________________________

Capacity(ies) Claimed by Signer(s)

□ Signer's Name:_____________________            □ Signer's
Name:_____________________
□ Corporate Officer ___ Title(s):_________            □ Corporate Officer ___
Title(s):_________
□ Partner -     □ Limited    □ General        □ Partner -     □ Limited    □
General
□ Individual    □ Attorney in Fact            □ Individual    □ Attorney in Fact
□ Trustee    □ Guardian or Conservator            □ Trustee    □ Guardian or
Conservator
□ Other: ____________________________            □ Other:
____________________________
Signer Is Representing: _______________            Signer Is Representing:
_______________
__________________________________            ________________________________

©2014 National Notary Association ·www.NatlonalNotary.org • 1-800-US NOTARY
(1-800-876-6827) Item #5907

161

--------------------------------------------------------------------------------

CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT                CIVIL CODE § 1189

A notary public or other officer completing this certificate verifies only the
identity of the individual who signed the document to which this certificate is
attached, and not the truthfulness, accuracy, or validity of that document.

State of California            )
County of Orange            )

On September 7, 2017, before me,         J. Lemburg, Notary
Public                ,
Date                 Here Insert Name and Title of the Officer    
personally appeared                Dukku Lee                
Name(s) of Signer(s)
_______________________________________________________________________________

who proved to me on the basis of satisfactory evidence to be the person(s) whose
name(s) is/are subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized capacity(ies), and
that by his/her/their signature(s) on the instrument the person(s), or the
entity upon behalf of which the person(s) acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California
that the foregoing paragraph is true and correct.

WITNESS my hand and official seal.

Signature /s/ J. Lemburg            
Signature of Notary Public
[SEAL]

My commission expires October 2, 2019

    Place Notary Seal Above
-----------------------------------------------------------OPTIONAL--------------------------------------------------------
Though this section is optional, completing this information can deter
alteration of the document or
fraudulent reattachment of this form to an unintended document.

Description of Attached Document
Title or Type of Document:_________________________ Document Date:
_______________
Number of Pages: _______ Signer(s) Other Than Named Above:
______________________________

Capacity(ies) Claimed by Signer(s)
Signer's Name:_____________________            □ Signer's
Name:_____________________
□ Corporate Officer ___ Title(s):_________            □ Corporate Officer ___
Title(s):_________
□ Partner -     □ Limited    □ General        □ Partner -     □ Limited    □
General
□ Individual    □ Attorney in Fact            □ Individual    □ Attorney in Fact
□ Trustee    □ Guardian or Conservator            □ Trustee    □ Guardian or
Conservator
□ Other: ____________________________            □ Other:
____________________________
Signer Is Representing: _______________            Signer Is Representing:
_______________
__________________________________            _________________________________
 

©2014 National Notary Association ·www.NatlonalNotary.org • 1-800-US NOTARY
(1-800-876-6827) Item #5907

--------------------------------------------------------------------------------

REFERENCES TO EXHIBITS IN
PARTICIPATION AGREEMENT

Exhibit No.        References in Agreement         Subject Matter
I        §§ 2.10, 6.1                    Real Property
II        [Omitted]
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, 22.7-8        A&G Expense            
VII        [Omitted]
VIII        §§ 18.4, 19.4, 20.5, 21.4            Adjustment of Voting

--------------------------------------------------------------------------------

EXHIBIT I

--------------------------------------------------------------------------------

EXHIBIT I

This Exhibit I to the Exit Date Amendment Amending and Restating 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:    NE 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

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conformednewexitdatea_image1.jpg [conformednewexitdatea_image1.jpg]

Exh. I - 4

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conformednewexitdatea_image2.jpg [conformednewexitdatea_image2.jpg]

Exh. I - 5

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conformednewexitdatea_image3.jpg [conformednewexitdatea_image3.jpg]

Exh. I - 6

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conformednewexitdatea_image4.jpg [conformednewexitdatea_image4.jpg]

Exh. I - 7

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conformednewexitdatea_image5.jpg [conformednewexitdatea_image5.jpg]

Exh. I - 8

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conformednewexitdatea_image6.jpg [conformednewexitdatea_image6.jpg]

Exh. I - 9

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conformednewexitdatea_image7.jpg [conformednewexitdatea_image7.jpg]

Exh. I - 10

--------------------------------------------------------------------------------

EXHIBIT II

[Omitted]

--------------------------------------------------------------------------------

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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC-
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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
100
%
TEP -
0
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
77.297
%
TEP -
0
%
UAMPS -
7.028
%
Farmington -
8.475
%
 
 
LAC -
7.2
%
 
 
 
 
 
 
 
 

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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
77.297
%
TEP -
0
%
UAMPS -
7.028%
Farmington -
8.475
%
 
 
LAC -
7.2
%
 
 
 
 
 
 
 
 

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 -
66.344
%
TEP -
20.068
%
UAMPS -
4.203
%
Farmington -
5.076
%
 
 
LAC -
4.309
%
 
 
 
 
 
 
 
 

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.

3.1    SO2 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)

3.2    SO2 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
 
5482
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
 
8782
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
 
20,782

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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
100
%
TEP -
0
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
77.297
%
TEP -
0
%
UAMPS -
7.028
%
Farmington -
8.475
%
 
 
LAC -
7.2
%
 
 
 
 
 
 
 
 

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
%
UAMPS -
0
%
Farmington -
0
%
 
 
LAC -
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 -
77.297
%
TEP -
0
%
UAMPS -
7.028
%
Farmington -
8.475
%
 
 
LAC-
7.2
%
 
 
 
 
 
 
 
 

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 -
70.381
%
TEP -
19.8
%
UAMPS -
3.017%
Farmington -
3.679
%
 
 
LAC -
3.123
%
 
 
 
 
 
 
 
 

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.

3.1    SO2 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)

3.2    SO2 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
 
TEP
Variable split based on generation by unit
Farmington
 
LAC
 
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

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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

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

Exh. VI - 2

--------------------------------------------------------------------------------

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 year’s 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

[Omitted]

--------------------------------------------------------------------------------

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.

Exh. VIII - 1

--------------------------------------------------------------------------------

 
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
%
 
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
%
 
12.5
%
 
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
%
 

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

2 Computed 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 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 3 & 4 Common
 
5
 
4
Participant A
15.00
%
 
20.536
%
 
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
%
 
Participant B
32.50
%
 
35.268
%
 
Participant C
12.50
%
 
16.964
%
 
Participant D
12.50
%
 
0.00
%
 
Participant E
10.00
%
 
12.500
%
 

3 Computed 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) = 1/2 (28.571%) + 1/2 (12.500%) = 20.536%

4 Computed 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