Document:

exv10w1

 

Exhibit 10.1

Confidential Materials omitted and filed separately with the Securities and

Exchange Commission. Asterisks denote omissions.

AMENDED

AND

RESTATED

COAL SUPPLY AGREEMENT

Dated August 24, 1998

 

 

Table of Contents

	 	 	 	 	 
	 	 	Page	 
	1. DEFINITIONS
	 	 	2	 
	2. SALE AND PURCHASE OF COAL; DEDICATION OF RESERVES
	 	 	7	 
	3. TERM
	 	 	7	 
	3.1. Initial Term
	 	 	7	 
	3.2. Extension
	 	 	7	 
	4. GOVERNANCE
	 	 	7	 
	5. EXECUTIVE COMMITTEE
	 	 	8	 
	5.1. Establishment and Purpose
	 	 	9	 
	5.2. Decisions
	 	 	9	 
	5.3. Meetings
	 	 	9	 
	5.4. Notice
	 	 	9	 
	5.5. Quorum
	 	 	9	 
	5.6. Minutes
	 	 	9	 
	5.7. Action Without Meeting
	 	 	9	 
	5.8. Costs
	 	 	10	 
	5.9. No Modification of Agreement
	 	 	10	 
	5.10. Cooperation
	 	 	10	 
	6. MINE OPERATING COMMITTEE
	 	 	10	 
	6.1. Establishment and Purpose
	 	 	10	 
	6.2. Decisions
	 	 	11	 
	6.3. Meetings
	 	 	11	 
	6.4. Notice
	 	 	12	 
	6.5. Quorum
	 	 	12	 
	6.6. Minutes
	 	 	12	 
	6.7. Action Without Meeting
	 	 	12	 
	6.8. Costs
	 	 	12	 
	6.9. No Modification of Agreement
	 	 	12	 
	6.10. Cooperation of the Parties
	 	 	13	 
	7. ANNUAL OPERATING PLAN
	 	 	13	 
	7.1. Operations Pursuant to Annual Operating Plan
	 	 	13	 
	7.2. Purposes and Components of Annual Operating Plan
	 	 	13	 
	7.3. Review and Approval of Annual Operating Plan
	 	 	14	 
	7.4. Capital Budget Approval
	 	 	15	 
	7.5. Development of Annual Incentive Fee Plan Component
	 	 	16	 
	7.6. Decisions on Annual Operating Plan
	 	 	17	 
	7.7. Revisions to the Approved Annual Operating Plan
	 	 	18	 
	7.7.1. Revisions resulting from material changes
	 	 	18	 
	7.7.2. Other proposed revisions to an Approved Annual Operating Plan
	 	 	19	 
	7.8. Reporting on Approved Annual Operating Plan
	 	 	19	 
	7.9. Emergency
	 	 	21	 
	8. RESOLUTION OF DISPUTES
	 	 	21	 

AMENDED AND RESTATED COAL SUPPLY AGREEMENT
PAGE i

 

 

Table of Contents

(continued)

	 	 	 	 	 
	 	 	Page	 
	8.1. Failure to Approve an Annual Operating Plan, Approve a Proposed Revision to an Approved Operating
Plan or Agree Upon the Earned Portion of the Incentive Fee Per Ton
	 	 	21	 
	8.2. Disputes Regarding Cost Charges Other Than Earned Portion of the Incentive Fee Per Ton
	 	 	22	 
	8.3. Arbitration Process
	 	 	22	 
	8.4. Resolution of Other Disputes
	 	 	23	 
	9. DELIVERY, WEIGHING AND TRANSPORTATION
	 	 	24	 
	9.1. Point of Delivery
	 	 	24	 
	9.2. Weight and Scales
	 	 	24	 
	9.3. Scheduling Deliveries
	 	 	24	 
	10. QUALITY
	 	 	25	 
	10.1. Applicable to Coal from Seller’s Mine
	 	 	25	 
	10.2. Coal Specifications
	 	 	25	 
	10.3. Average Coal Quality and Characteristics
	 	 	25	 
	10.4. Minimum and Maximum Characteristics
	 	 	26	 
	10.5. Nonconforming Coal
	 	 	26	 
	11. SAMPLING AND ANALYSIS
	 	 	27	 
	12. PRICE AND PAYMENT
	 	 	27	 
	12.1. Determination of Price
	 	 	27	 
	12.2. Price Components
	 	 	27	 
	12.3. Fixed Costs
	 	 	28	 
	12.3.1. Depreciation rates
	 	 	28	 
	12.3.2. A&G expenses
	 	 	28	 
	12.3.3. Payment of Fixed Costs
	 	 	29	 
	12.4. Variable Charge
	 	 	29	 
	12.4.1. Imported or exported equipment
	 	 	29	 
	12.4.2. Payment of Variable Charge
	 	 	30	 
	12.5. Return on Investment
	 	 	30	 
	12.5.1. ROI rate for pre-July 1, 2000 investments
	 	 	30	 
	12.5.2. ROI rate on post-June 30, 2000 investments
	 	 	30	 
	12.5.3. Melding of ROI rates for post-June 30, 2000 investments
	 	 	31	 
	12.5.4. Investment Base
	 	 	31	 
	12.5.5. Intangible Capital Investment
	 	 	31	 
	12.5.6. Payment of Return on Investment
	 	 	32	 
	12.6. Fixed Fee Per Ton
	 	 	33	 
	12.7. Incentive Fee Per Ton
	 	 	33	 
	12.8. Royalties and Production Taxes
	 	 	35	 
	12.9. Invoices
	 	 	35	 

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT
PAGE ii

 

 

Table of Contents

(continued)

	 	 	 	 	 
	 	 	Page	 
	12.10. Credits for Third Party Sales
	 	 	35	 
	12.11. Impact of Force Majeure
	 	 	37	 
	12.12. Cost Changes and Monthly Reports of Costs
	 	 	37	 
	12.13. Disputed Charges
	 	 	38	 
	12.14. Changes in Applicable Law or Circumstances
	 	 	38	 
	13. PRICE ADJUSTMENT FOR Btu CONTENT
	 	 	39	 
	13.1. Applicable Provisions
	 	 	39	 
	13.2. Coal Exceeding [**] Btu/lb
	 	 	39	 
	13.3. Cents Per MMBtu Below Budgeted Cost
	 	 	39	 
	13.4. Cents Per MMBtu Above Budget Cost
	 	 	39	 
	13.5. No Price Adjustment for Btu Deficiencies Arising in Certain Circumstances
	 	 	39	 
	14. QUANTITY, THIRD PARTY SALES AND PURCHASES
	 	 	40	 
	14.1. Requirements Obligation
	 	 	40	 
	14.2. Sales to Third Parties
	 	 	40	 
	14.3. Coal from Outside Sources
	 	 	40	 
	14.3.1. Seller to obtain offers
	 	 	41	 
	14.3.2. Terms of offers
	 	 	41	 
	14.3.3. Seller to act as exclusive agent for Buyers to obtain Outside Coal
	 	 	41	 
	14.3.4. Price for Outside Coal
	 	 	42	 
	14.3.5. Potential third party [**] Outside Coal to Seller as agent
	 	 	42	 
	15. FINAL RECLAMATION COSTS
	 	 	42	 
	15.1. Reclamation Account
	 	 	42	 
	15.2. Obligations of Seller and Non-Puget Buyers to Each Other For Final Reclamation
	 	 	43	 
	15.3. Obligations of Seller and Puget to Each Other for Final Reclamation
	 	 	44	 
	15.4. Closing of the Reclamation Account and Creation and Maintenance of Seller’s Account
	 	 	46	 
	16. FORCE MAJEURE AND PLANT OUTAGES
	 	 	47	 
	16.1. Force Majeure
	 	 	47	 
	16.2. Plant Inoperability
	 	 	47	 
	16.3. Depreciation Suspension
	 	 	48	 
	17. WAIVERS AND REMEDIES
	 	 	48	 
	17.1. Non-waiver
	 	 	48	 
	17.2. Right to Cure
	 	 	48	 
	17.3. Seller’s Default
	 	 	48	 
	17.4. Buyers’ Remedies
	 	 	49	 
	18. SUCCESSORS AND ASSIGNS
	 	 	49	 
	18.1. Assignment of Buyer’s Interest
	 	 	50	 
	18.2. Assignment of Seller’s Interest
	 	 	50	 
	19. LAW GOVERNING CONSTRUCTION OF AGREEMENT
	 	 	51	 

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PAGE iii

 

 

Table of Contents

(continued)

	 	 	 	 	 
	 	 	Page	 
	20. NOTICES AND REPORTS
	 	 	51	 
	21. RECORDS TO BE KEPT
	 	 	52	 
	21.1. Maintenance and Provision of Information
	 	 	52	 
	21.2. Audit Rights
	 	 	52	 
	22. NO SALES AGENT
	 	 	53	 
	23. OPERATOR
	 	 	53	 
	24. PERPETUITIES
	 	 	53	 
	25. COMPLIANCE
	 	 	53	 
	26. [**]
	 	 	53	 
	27. SEVERAL LIABILITY
	 	 	53	 
	28. CONFIDENTIALITY
	 	 	54	 
	28.1. Labeling Information “Confidential”
	 	 	54	 
	28.2. Duty Not to Disclose
	 	 	54	 
	28.3. Notice Prior to Compulsory Disclosure
	 	 	54	 
	29. EXECUTION OF AGREEMENT
	 	 	54	 
	30. COUNTERPARTS
	 	 	54	 
	 
	 	 	 	 
	EXHIBIT A — OWNERSHIP OF CAPACITY
	EXHIBIT B — PRICE PROVISIONS APPLICABLE PRIOR TO JULY 1, 2000
	EXHIBIT C — MAP SHOWING AREA C CONTRACT BOUNDARY
	EXHIBIT D — DETERMINATION OF TONNAGE INCREASE AND EXAMPLE COMPUTATIONS OF BRU PRICE ADJUSTMENT
	EXHIBIT E — ENTECH, INC. INDEMNIFICATION AGREEMENT

AMENDED AND RESTATED COAL SUPPLY AGREEMENT
PAGE iv

 

 

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

     THIS AMENDED AND RESTATED COAL SUPPLY AGREEMENT, is entered into as of this 24th day of
August, 1998, by and among The Montana Power Company (“Montana”), a Montana corporation, Puget
Sound Energy, Inc. (“Puget”), a Washington corporation, The Washington Water Power Company (“Water
Power”), a Washington corporation, Portland General Electric Company (“Portland”), an Oregon
corporation, PacifiCorp (“Pacific”), an Oregon corporation, and Western Energy Company (“WECO”), a
Montana corporation (herein called “Seller”). Montana, Puget, Water Power, Portland and Pacific
are sometimes referred to herein individually as “Buyer” and in the plural as the “Buyers”.

RECITALS

     A. Buyers constructed, own and operate two coal fired steam-electric generating plants (“Units
3 & 4”) near Colstrip, Montana, adjoining the coal lands of Seller, based upon the assurance of a
dependable supply of coal from the Seller of specified quality and characteristics for the useful
life of the plants. Units 3 & 4 consist of two 805 megawatt gross rating generating units which
were designed and constructed to operate with coal of the quality and characteristics described in
Section 10 of this Amended and Restated Coal Supply Agreement.

     B. Buyers would not have designed and constructed units of this type at Colstrip but for the
availability of a dependable supply of coal from Area C of Seller’s Rosebud Mine through at least
December 31, 2019.

     C. Seller owns or controls in Rosebud County, Montana, adequate reserves of sub-bituminous
coal from which it can supply Buyers’ coal requirements for Units 3 & 4 through at least December
31, 2019.

     D. Buyers previously entered into a Coal Supply Agreement dated July 2, 1980. Such Coal Supply
Agreement was amended effective July 10, 1981, September 1, 1981, September 14, 1987 and January 1,
1988. The Coal Supply Agreement was also the subject of an arbitration decision dated May 6, 1996.

     E. The Coal Supply Agreement provided opportunities for a number of price reopeners in the
year 2000 and a number of dates thereafter. Buyers and Seller desire to amend such Coal Supply
Agreement now to resolve these price reopeners and to restructure it to align better their economic
interests. Buyers and Seller desire to enter into this Amended and Restated Coal Supply Agreement
(the “Agreement”), pursuant to which they are amending and restating in its entirety the Coal
Supply Agreement, as amended, into this one Agreement.

     F. It is essential to Seller, because of the substantial capital investment it made and must
make in order to have the capability to supply Buyers’ requirements, that Buyers purchase all of
their coal requirements for Units 3 & 4 as expressly provided in this Agreement.

AGREEMENT

     NOW, THEREFORE, in consideration of the mutual covenants and agreements herein stated, and the
performance thereof, the Parties hereto agree as follows:

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 1

 

1. DEFINITIONS

     Whenever used in this Agreement with initial letters capitalized (whether in the singular or
the plural), the following words and terms shall have the following meanings:

     1.1 “A & G” means those administrative and general expenses of the entire Mine which are
apportioned to coal delivered under this Agreement in the manner described in subsection 12.3.2.

     1.2 “Agreement” means this Amended and Restated Coal Supply Agreement.

     1.3 “Annual Incentive Fee Plan” means the annual plan agreed upon by Seller and the Mine
Operating Committee each Year pursuant to subsections 7.5 and 7.6 establishing standards to be used
to determine the Earned Portion of the Incentive Fee Per Ton for the next Year. The Annual
Incentive Fee Plan shall be a component of the Annual Operating Plan.

     1.4 “Annual Operating Plan” means the annual operating plan prepared and submitted each Year
pursuant to subsections 7.1-7.3 of this Agreement.

     1.5 “Approved Annual Operating Plan” means the Annual Operating Plan that is approved pursuant
to subsections 7.3 and 7.6 of this Agreement.

     1.6 “Approved Capital Budget” means the Capital Budget set forth in the Approved Annual
Operating Plan.

     1.7 “Approved Operating Budget” means the Operating Budget set forth in the Approved Annual
Operating Plan.

     1.8 “Arbitration Decision” has the meaning ascribed to it in subsection 15.1.

     1.9 “Area C” means the portion of the Mine described on Exhibit C to this Agreement.

     1.10 “ASTM” means the American Society for Testing Materials.

     1.11 “Btu” means a British thermal unit and, in the appropriate context, the plural of that
term, which means the amount of heat required to raise the temperature of one pound of distilled
water from 59 degrees Fahrenheit to 60 degrees Fahrenheit at a constant pressure of 14.73 pounds
per square inch absolute.

     1.12 “Capacity” means the rate at which electrical energy can be generated from Units 3 & 4,
expressed in net megawatts (MW). Each Buyer’s percentage ownership of the Capacity is set forth on
Exhibit A to this Agreement.

     1.13 “Capital Assets” means any tangible or intangible additions, betterments, or replacements
to the Mine and assets, equipment and reserves related thereto (including lease acquisitions, major
repairs and relocation of facilities such as power lines and roads) that (i) are made by Seller,
(ii) would ordinarily be capitalized in accordance with generally accepted

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 2

 

accounting practices and
(iii) in the case of intangibles, are within the meaning of Intangible Capital Investment.

     1.14 “Capital Budget” means the Capital Budget component of the Annual Operating Plan
described in subsection 7.2(c).

     1.15 “Capital Equipment” has the meaning ascribed to it in subsection 12.10(f).

     1.16 “Commodity Charge” means the component of Price described in subsection 12.2 which
includes the Variable Charge, ROI, Fixed Fee Per Ton, Incentive Fee Per Ton, and Royalties and
Production Taxes.

     1.17 “Confidential Information” has the meaning ascribed to it in Section 28.

     1.18 “Consolidated Net Worth” has the meaning ascribed to it in subsection 15.2.D.

     1.19 “Current Reclamation” has the meaning ascribed to it in Section 15.

     1.20 “Distribution Notice” has the meaning ascribed to it in subsection 12.9.

     1.21 “Earned Portion of the Incentive Fee Per Ton” has the meaning ascribed to it in
subsection 12.7(b).

     1.22 “Effective Date” has the meaning ascribed to it in subsection 3.1.

     1.23 “Environmental and Safety Plan” means the component of the Annual Operating Plan
described in subsection 7.2(d).

     1.24 “Executive Committee” means the Committee established pursuant to subsection 5.1(a).

     1.25 “Fixed Costs” means the costs described in subsection 12.3.

     1.26 “Fixed Fee Per Ton” means the fee described in subsection 12.6.

     1.27 “Force Majeure” has the meaning ascribed to it in subsection 16.1.

     1.28 “ [**]” means the [**] in [**] and [**].

     1.29 “Incentive Fee Per Ton” means the fee described in subsection 12.7(a).

     1.30 “Intangible Capital Investment” means the investments described in subsection 12.5.5.

     1.31 “Investment Base” has the meaning ascribed to it in subsection 12.5.4.

     1.32 “Major Equipment” means the equipment described in subsection 12.10(f).

     1.33 “Merchant Plant Practice” means those practices, methods and acts that:

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 3

 

	 	(a)	 	a prudent person owning and operating both the
Mine and Units 3 & 4 over their useful economic life and supplying coal
to Units 3 & 4 exclusively from Area C of the Mine would engage in
(taking into consideration factors such as optimization of its return
on investment in both the Mine and Units 3 & 4 and short-term and
long-term opportunities to minimize costs that may present themselves
over the Term of this Agreement, and the costs that would be incurred
in using coal to produce electricity from Units 3 & 4 for sale into a
competitive electricity marketplace, recognizing that such costs
include the fees and other payments to Seller pursuant to this
Agreement) to supply coal of the quality and in the quantity
contemplated by this Agreement for purposes of producing power at the
lowest practical cost for sale into a competitive electricity
marketplace from Units 3 & 4 with safety, reliability, efficiency,
expedition and economy, and
	 
	 	(b)	 	are consistent with “good mining practice” and
“least-cost mining” (each, as hereinafter defined) and are taken in
good faith.

For purposes of this Agreement,

	 	(i)	 	“good mining practice” means:
	 
	 	 	 	(A)     those practices, methods and acts which when engaged in
are commonly used in prudent mining engineering and
operations to operate coal mines similar to the Mine lawfully
and with safety, reliability, efficiency, expedition and
economy, or
	 
	 	 	 	(B) if there are no such commonly used practices, methods and
acts, those practices, methods and acts which in the exercise
of reasonable judgment considering the facts known when
engaged in, could have been expected to achieve the desired
result consistent with applicable law, safety, reliability,
efficiency, expedition and economy;

and

(ii) “least-cost mining” means the mining of coal in the manner that
minimizes the cost of coal supplied to Units 3 & 4 in order to
produce electricity at the lowest practical cost and sell that
electricity into a competitive marketplace, taking into consideration
such factors as overburden and coal removal, haul distance, coal
quality, and Outside Coal opportunities.

     1.34 “Mine” means the Rosebud Mine located near Colstrip, Montana, plus all assets, plant and
equipment related thereto.

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 4

 

     1.35 “Mine Operating Committee” has the meaning ascribed to that term in subsection 6.1(a) of
this Agreement.

     1.36 “Mine Plan” means the component of the Annual Operating Plan described in subsection
7.2(a).

     1.37 “MMBtu” means one million (1,000,000) Btu.

     1.38 “Non-Puget Buyers” means Portland, Montana, Water Power and Pacific.

     1.39 “Operating Budget” means the component of the Annual Operating Plan described in
subsection 7.2(b).

     1.40 “Operator” means the entity designated to operate Units 3 & 4 pursuant to the Units 3 & 4
Ownership and Operation Agreement.

     1.41 “Original Coal Supply Agreement” means the Coal Supply Agreement among the Parties dated
as of July 2, 1980, as amended by (i) Amendment No. 1 to Coal Supply Agreement, dated as of July
10, 1981; (ii) Amendment No. 2 to Coal Supply Agreement, dated as of September 1, 1981; (iii)
Amendment No. 3 to the Coal Supply Agreement, dated as of September 14, 1987; and (iv) Amendment
No. 4 to Coal Supply Agreement, dated as of January 1, 1988. The Original Coal Supply Agreement was
also subject to an arbitration decision dated May 6, 1996.

     1.42 “Outside Coal” means coal purchased in accordance with subsection 14.3 of this Agreement,
and excludes coal produced from the Mine.

     1.43 “Outside Coal Commitment” means a contract for the acquisition of Outside Coal.

     1.44 “Party” means Seller or any one of Buyers, and “Parties” means all Buyers and Seller
unless the context otherwise indicates.

     1.45 “Point of Delivery” has the meaning ascribed to that term in subsection 9.1.

     1.46 “Price” means the Price described in Section 12 to be paid by Buyers for coal produced
from Area C.

     1.47 “Puget Coal Fraction” has the meaning ascribed to it in subsection 15.3(b).

     1.48 “Puget Obligation” has the meaning ascribed to it in subsection 15.3 (b).

     1.49 “Puget Reclamation Account Balance” has the meaning ascribed to that term in subsection
15.3(a).

     1.50 “Qualified Operating Lease” means an equipment operating lease (as opposed to a capital
lease, as determined in accordance with generally accepted accounting principles consistently
applied) of an asset by Seller for use or consumption in Area C that (a) is entered

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 5

 

into by Seller
with a third party that is not affiliated with any Party, (b) has a term that is
materially shorter than the useful life of such asset, as determined at the time the asset is
originally placed in service by its owner, and (c) unless otherwise mutually agreed by the Parties,
contains no option to purchase the asset.

     1.51 “Reclamation” has the meaning ascribed to it in Section 15.

     1.52 “Reclamation Account” has the meaning ascribed to it in subsection 15.1.

     1.53 “ROI” has the meaning ascribed to such term in subsection 12.5.

     1.54 “Royalties and Production Taxes” means charges for royalties and production taxes imposed
upon and paid by Seller with respect to coal delivered hereunder.

     1.55 “Seller’s Account” has the meaning ascribed to it in subsection 15.4(b).

     1.56 “Subsection 15.2 Final Reclamation Estimate” has the meaning ascribed to it in subsection
15.4(b).

     1.57 “Subsection 15.2 Final Reclamation” has the meaning ascribed to it in Section 15.

     1.58 “Subsection 15.3 Final Reclamation” has the meaning ascribed to it in subsection I5.3(b).

     1.59 “Submission Date” means the date described in subsection 7.7.1 on which Seller or a
Buyer(s) has delivered to the other Parties a proposed revision to the Approved Annual Operating
Plan.

     1.60 “Term” has the meaning ascribed to it in subsection 3.1.

     1.61 “Third Party Transferee” has the meaning ascribed to it in subsection 18.2.

     1.62 “Ton” shall mean 2,000 pounds.

     1.63 “Tonnage Increase” has the meaning ascribed to it in subsection 13.4.

     1.64 “Total Area C Tons Mined” has the meaning ascribed to it in subsection 15.3(b).

     1.65 “Treasury Bond” means the 30-year US Treasury Bond issued by the United States of
America.

     1.66 “Treasury Bond Rate” means the yield to maturity on the most recently issued Treasury
Bonds at a given time as determined by market transactions and as reported in The Wall Street
Journal.

     1.67 “Units 3 & 4” means Colstrip Units 3 & 4.

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     1.68 “Units 3 & 4 Ownership and Operation Agreement” means the Ownership and Operation
Agreement among Buyers, dated as of May 6, 1981, as amended.

     1.69 “Variable Charge” shall mean the charge described in subsection 12.4.

     1.70 “Variable Cost” has the meaning ascribed to it in subsection 13.3.

     1.71 “Variable Cost per MMBtu” has the meaning ascribed to it in subsection 13.3.

     1.72 “Year” means a calendar year.

     1.73 “Year One” has the meaning ascribed to it in subsection 7.2(a).

     1.74 “Year Two” has the meaning ascribed to it in subsection 7.2.(a).

     1.75 “Years Three, Four and Five” has the meaning ascribed to it in subsection 7.2(a).

2. SALE AND PURCHASE OF COAL; DEDICATION OF RESERVES

     Seller agrees to sell and deliver, and Buyers agree to buy and receive, all of the coal
required for Units 3 & 4 upon the terms and conditions set forth in this Agreement. Seller
dedicates coal reserves it now owns or controls or may hereafter reasonably acquire in Rosebud
County, Montana, in Area C sufficient to satisfy the requirements of Buyers for Units 3 & 4 through
the Term of this Agreement.

3. TERM

     3.1. Initial Term.

     The “Effective Date” of this Agreement shall be January 1, 1998. The “Term” of this Agreement
shall be from January 1, 1998 through December 31, 2019.

     3.2. Extension.

     If on December 31, 2019, there will be coal available on Seller’s coal lands which can be
mined economically for use in producing power from Units 3 & 4 and Units 3 & 4 are capable of
producing power economically using such coal, this Agreement will be extended on terms mutually
agreeable to Seller and Buyers, reflecting then-existing market conditions for such available coal.
On or after January 1, 2018, but no later than November 1, 2018, Seller or any Buyer may by written
notice to the other Parties require that such extension negotiations occur during 2018. If, despite
extension negotiations, Seller and Buyers do not reach agreement by December 31, 2018, then all
Parties shall have the right to make arrangements based on this Agreement terminating December 31,
2019.

4. GOVERNANCE

     Subject to the terms of this Agreement and Approved Annual Operating Plans, Seller as owner
and operator of the Mine shall have the discretion to operate the Mine as it determines is

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 7

 

necessary and appropriate to comply with applicable laws, regulation and leases. Buyers, through
the Mine Operating Committee, shall jointly monitor Seller’s performance and shall consider and
approve or disapprove Annual Operating Plans. All Parties shall be represented on the Executive
Committee, which shall attempt to resolve issues not resolved by the Seller and the Mine Operating
Committee and which shall also provide policy guidance consistent with Merchant Plant Practice and
this Agreement. The functions and activities of the Mine Operating Committee and Executive
Committee are described in additional detail below. The Parties intend that Buyers’ participation
in the functions and activities of the Mine Operating Committee and the Executive Committee shall
not make the Buyers partners in the ownership or operation of the Mine, or create any partnership
or joint venture relationship related thereto. The relationship of Seller to Buyers shall be that
of independent contractor.

5. EXECUTIVE COMMITTEE

     5.1. Establishment and Purpose.

	 	(a)	 	The Parties hereby establish an Executive
Committee (the “Executive Committee”) consisting of one representative
with policy making authority from each Party. Upon execution of this
Agreement, each Party shall promptly designate its representative on
the Executive Committee by written notice given to the other Parties.
Each Party may appoint an alternate representative to act in the
absence of its designated representative.
	 
	 	(b)	 	Buyers shall from time to time select a chair
of the Executive Committee from among the members of the Executive
Committee
by the affirmative vote of Buyers owning in the aggregate not less
than fifty-one percent (51%) of the Capacity; provided,
however, that the vote and share of Capacity of any Party
that owns or controls or is in common control with Seller shall be
disregarded for purposes of determining whether the required
fifty-one percent (51%) has been obtained. As used in the preceding
sentence, “control” means possession, directly or indirectly, of the
power to direct or cause direction of management and policies through
ownership of voting securities, contract, voting trust or otherwise.
The chair of the Executive Committee shall call meetings and
establish agendas in consultation with the other Parties.
	 
	 	(c)	 	The Executive Committee shall:
	 
	 	 	 	(i) Provide policy-level guidance to Seller and the Mine Operating
Committee concerning Merchant Plant Practice and this Agreement; and
	 
	 	 	 	(ii) Resolve disputes as provided in Section 8.

 AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     5.2. Decisions.

     The Executive Committee shall operate on a consensus basis in providing policy-level guidance
to the Seller and Mine Operating Committee and must be unanimous in the resolution of disputes.

     5.3. Meetings.

     The Executive Committee shall meet at least once annually in February or March or more often
by mutual agreement or as necessary to resolve disputes referred to the Executive Committee.
Meetings shall be held at a place designated by the chair of the Executive Committee.

     5.4. Notice.

     The chair of the Executive Committee shall give the other Parties not less than thirty days’
notice of the annual meeting of the Executive Committee and not less than five days’ notice of all
other meetings of the Executive Committee. Each notice shall include the location of the meeting
and an agenda prepared by the chair. The Parties may waive notice by unanimous written consent.

     5.5. Quorum.

     A quorum for a meeting shall exist if each Party’s representative is present;
provided, however, that if a Party fails to attend two consecutive properly called
and noticed meetings, then a quorum for the second of such two consecutive meetings shall exist if
each other Party’s representative is present.

     5.6. Minutes.

     The chair of the Executive Committee shall maintain minutes of Executive Committee meetings
and shall distribute the minutes to the Parties’ representatives within 15 days after each meeting
of the Executive Committee. The minutes, when approved by all of the Parties, shall be the official
record of the decisions made by the Executive Committee.

     5.7. Action Without Meeting.

     In lieu of meetings, the Executive Committee may hold telephone conference calls with all
Parties’ representatives simultaneously. The Executive Committee, in lieu of deciding any matter at
a meeting or by telephone conference, may act by instrument in writing signed by each Party’s
representative.

     5.8. Costs.

     Each Party shall bear for its own account all costs incurred by that Party’s representative on
the Executive Committee.

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     5.9. No Modification of Agreement.

     The Executive Committee may not modify, amend, revise or otherwise change the terms and
conditions set forth in this Agreement.

     5.10. Cooperation.

     The Parties shall cooperate with and provide the Executive Committee with information
reasonably necessary for the Executive Committee to perform its duties.

6. MINE OPERATING COMMITTEE

     Buyers shall participate with Seller in the planning and oversight of Area C operations
through the Mine Operating Committee. Although the Mine Operating Committee and Seller
shall work together on matters of joint concern, Seller shall not be a member of the Mine
Operating Committee.

     6.1. Establishment and Purpose.

	 	(a)	 	A Mine Operating Committee (the “Mine Operating
Committee”) is hereby established consisting of one representative
appointed by each Buyer. Upon execution of this Agreement, each Buyer
shall promptly designate its representative on the Mine Operating
Committee by written notice given to the other Parties. Each Buyer may
appoint one or more alternates to act in the absence of its designated
representative. Each representative on the Mine Operating Committee may
(at such representative’s Party’s cost) have such other personnel
present at meetings of the Mine Operating Committee as such
representative may desire. A designated representative of the Operator
shall be a non-voting, ex officio member of the Mine Operating
Committee.
	 
	 	(b)	 	Buyers shall from time to time select a chair
of the Mine Operating Committee by the affirmative vote of Buyers
owning in the aggregate not less than fifty-one percent (51%) of the
Capacity; provided, however, that the vote and share of
Capacity of any Buyer that owns or controls Seller shall be disregarded
for purposes of determining whether the required fifty-one percent
(51%) has been obtained. As used in the preceding sentence, “control”
means possession, directly or indirectly, of the power to direct or
cause direction of management and policies through ownership of voting
securities, contract, voting trust or otherwise. The chair of the Mine
Operating Committee shall be responsible for calling meetings and
establishing agendas in consultation with other Buyers.
	 
	 	(c)	 	The Mine Operating Committee shall:

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	 	 	 	(i) Provide Seller with reports and analysis of operations and
performance expectations with respect to Units 3 & 4 for use by
Seller in developing the Annual Operating Plan.
	 
	 	 	 	(ii) Review and approve or disapprove the Annual Operating Plan
(including all components thereof) and proposed revisions to
an Approved Annual Operating Plan as provided in subsections 7.3,
7.4, 7.5, 7.6 and 7.7 of this Agreement, review and approve or
disapprove acquisitions of Capital Assets as provided in subsections
7.4 and 7.8(a), and review monthly budget variance reports and
quarterly budget projection reports as contemplated in subsection
7.8(b);
	 
	 	 	 	(iii) Meet with Seller to review any action taken and expenditure
incurred by Seller in connection with an emergency affecting the
Mine;
	 
	 	 	 	(iv) Monitor Seller’s operations, performance and results relative to
the Approved Annual Operating Plan and the individual components of
such plan;
	 
	 	 	 	(v) Annually determine in consultation with Seller the Earned Portion
of the Annual Incentive Fee Per Ton pursuant to subsection 12.7(b);
and
	 
	 	 	 	(vi) Perform any other responsibility established for it under this
Agreement or otherwise assigned to it in writing by the Executive
Committee.

     6.2. Decisions.

     Each Buyer, acting through its appointed representative, shall have a vote on the Mine
Operating Committee. A Buyer’s representative or, in his/her absence, the alternate representative,
may cast the Buyer’s vote. The Mine Operating Committee shall make decisions by majority vote of
Capacity of the Buyers, except that approval of the Annual Operating Plan or any revision thereto
by the Mine Operating Committee and the determination of the Mine Operating Committee’s position
with respect to the Earned Portion of the Incentive Fee Per Ton pursuant to subsection 12.7(b)
shall be by the super-majority vote specified in subsection 7.6. All Buyers shall be bound by any
decision made by the Mine Operating Committee to approve or disapprove an Annual Operating Plan or
any revision thereto and any determination by the Mine Operating Committee of its position with
respect to the Earned Portion of the Incentive Fee Per Ton.

     6.3. Meetings.

     The Mine Operating Committee shall meet on or before June 15 of each Year to consider the
proposed Annual Operating Plan for the following Year and otherwise by mutual agreement.
Seller shall participate in meetings of the Mine Operating Committee as reasonably required to

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present, discuss and report on its proposed Annual Operating Plan, and to report, receive reports
and collaborate on matters of joint concern. Meetings of the Mine Operating Committee shall be held
at Colstrip, Montana or any other mutually agreed place.

     6.4. Notice.

     The chair of the Mine Operating Committee shall give not less than fifteen days’ notice to the
Parties of the meeting at which Seller presents its preliminary Annual Operating Plan and five
days’ notice of each other meeting of the Mine Operating Committee. Each meeting notice shall
include an agenda prepared by the chair in consultation with the Mine Operating Committee and
Seller. Buyers may waive notice by unanimous written consent.

     6.5. Quorum.

     A quorum for any meeting shall exist if each Buyer is represented by its member;
provided, however, that if a Buyer fails to attend two consecutive properly called
and noticed meetings, then a quorum for the second of such two consecutive meetings shall exist if
a representative of each other Buyer is present, in which case a majority or super-majority vote of
those other Buyers shall be considered the majority or super-majority vote of all Buyers for the
purposes of conducting properly noticed business.

     6.6. Minutes.

     The chair of the Mine Operating Committee shall maintain minutes of Mine Operating Committee
meetings and shall distribute them to the Parties’ representatives within fifteen (15) days after
each meeting. The minutes, when approved by all of the Buyers, shall be the official record of the
decisions made by the Mine Operating Committee. Copies of all minutes recording decisions of the
Mine Operating Committee shall be provided to Seller.

     6.7. Action Without Meeting.

     In lieu of meetings, the Mine Operating Committee may hold telephone conference calls with all
Buyers simultaneously and in which each Buyer shall be represented by its representative. The Mine
Operating Committee, in lieu of deciding any matter at a meeting or by telephone conference, may
act by instrument in writing signed by the representatives of each Buyer on the Mine Operating
Committee.

     6.8. Costs.

     Each Buyer shall bear for its own account all costs incurred by its representative on the Mine
Operating Committee.

     6.9. No Modification of Agreement.

     The Mine Operating Committee may not modify, amend, revise or otherwise change the terms and
conditions set forth in this Agreement.

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     6.10. Cooperation of the Parties.

     Seller shall respond promptly and in good faith to Buyers’ reasonable requests for supporting
information concerning the proposed Annual Operating Plan. The Parties shall cooperate with and
provide the Mine Operating Committee with information reasonably necessary for the Mine Operating
Committee to perform its duties.

7. ANNUAL OPERATING PLAN

     7.1. Operations Pursuant to Annual Operating Plan.

     Seller shall, in consultation with the Mine Operating Committee, prepare an Annual Operating
Plan for each Year beginning with 1999 pursuant to this Section 7, and such plan shall be
consistent with Merchant Plant Practice and the terms of this Agreement. Unless otherwise mutually
agreed in writing by all Parties, no Approved Annual Operating Plan shall obligate Seller to
supply, or any Buyer to purchase, coal from areas of the Mine other than Area C. Seller shall
conduct operations, incur expenses and acquire Capital Assets for Area C only pursuant to the
Approved Annual Operating Plan, except as otherwise provided in subsections 7.6 and 7.9.

     7.2. Purposes and Components of Annual Operating Plan.

     The purposes of the Annual Operating Plan shall be to provide Seller and Buyers through the
Mine Operating Committee with the tools to define fuel requirements and control costs to reasonable
levels. The Annual Operating Plan shall consist of the following components:

	 	(a)	 	A “Mine Plan” component setting forth (i)
monthly sequences under the proposed Annual Operating Plan for the Year
the Annual Operating Plan shall be effective (“Year One”), (ii)
quarterly sequences for mining in Area C for the subsequent Year (“Year
Two”), (iii) an annual sequence for mining in Area C for the subsequent
three Years (“Years 3, 4, and 5”) under a five-year mine plan, (iv) the
then-current life of mine plan for Area C and (v) annual coordination
of mining with coal delivery. The sequence
information shall include, but shall not be limited to, information
related to stripping ratios, equipment utilization, coal quality and
geological models.
	 
	 	(b)	 	An “Operating Budget” component which shall
include (i) the estimated Fixed Costs for the Year broken down by
component, (ii) the estimated Commodity Charge per ton for the Year
broken down by component, (iii) the projected coal quality for the
Year, (iv) the projected quantities of coal to be delivered to the
Point of Delivery during the Year, (v) the schedule of deliveries of
coal to the Point of Delivery, (vi) the source or sources of coal to be
delivered to Buyers during the Year and, if the supply of coal from
areas of the Mine other than Area C is mutually agreed upon by all
Parties, the quantity, quality, pricing and other pertinent details
with respect to coal to be supplied from areas of the Mine other than
Area C, (vii) the projected total quantities of coal to be mined

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	 	 	 	from
Area C during the Year, (viii) the estimated Price for the Year, as
determined under Section 12 of this Agreement, and (ix) all options to
satisfy all or part of the projected coal requirements of Units 3 & 4
by the acquisition of Outside Coal as contemplated by subsection 14.3,
to the extent known to Seller or made known to Seller by one or more
Buyers, with such acquisitions to be included in the proposed Operating
Budget if warranted by Merchant Plant Practice. Seller shall also
provide the Mine Operating Committee with a five-year plan projection
of the Operating Budget for information purposes only.
	 
	 	(c)	 	A “Capital Budget” component which shall (i) be
integrated with the Operating Budget, (ii) describe each proposed
Capital Asset in detail (including but not limited to equipment or
construction specifications), (iii) include cash flow forecasts, cost
estimates, and proposed dates for installation or replacement in
reasonable detail, and (iv) provide appropriate justification for each
proposed Capital Asset. Seller shall also provide the Mine Operating
Committee with a 5-year plan projection of the Capital Budget for
information purposes only.
	 
	 	(d)	 	An “Environmental and Safety Plan” component
which shall include environmental and safety goals and improvement
focus areas.
	 
	 	(e)	 	A “Personnel Plan” component which shall
include staffing, training, labor relations, employee gain sharing
plans and Seller’s goals.
	 
	 	(f)	 	An “Annual Incentive Fee Plan” component which
is developed as described in subsection 7.5 below.

     7.3. Review and Approval of Annual Operating Plan.

	 	(a)	 	On or before September 15, 1998 and on or
before May 1 of each Year beginning with 1999, Buyers shall provide
Seller with the following information that will assist Seller with the
preparation of the Annual Operating Plan:
	 
	 	 	 	(i) non-binding, good faith estimates of tonnage demand by month for
the upcoming Year and annually for an additional four years;
	 
	 	 	 	(ii) Buyers’ required and desired coal quality targets;
	 
	 	 	 	(iii) the timing of any planned outages at Units 3 & 4 during the
upcoming Year;

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	 	 	 	(iv) an analysis of Units 3 & 4 performance against cost and quality
parameters; and
	 
	 	 	 	(v) such other information as Buyers may deem relevant or that is
reasonably requested by Seller in connection with the preparation of
the Annual Operating Plan for the upcoming Year and the five-year
components of the Annual Operating Plan.
	 
	 	(b)	 	On or before October 15, 1998 and on or before
June 1 of each Year beginning with 1999, Seller shall submit a
preliminary Annual Operating Plan for the next Year to each member of
the Mine Operating Committee. Seller shall present and discuss the
preliminary Annual Operating Plan at a meeting called by the chair of
the Mine Operating Committee (in consultation with Seller) for that
purpose no later than June 15. Seller shall consider the comments of
the Mine Operating Committee and submit the proposed Annual Operating
Plan to the Mine Operating Committee by July 15. The Mine Operating
Committee shall provide Seller
with notice of any specific exceptions to the Annual Operating Plan
no later than August 15. Any such issues not resolved by September 1
by approval of an Annual Operating Plan by the Mine Operating
Committee shall promptly be presented to the Executive Committee for
resolution.

     7.4. Capital Budget Approval.

     The Parties agree that in the event Seller proposes to incur an expenditure for a Capital
Asset pursuant to the Capital Budget component of an Annual Operating Plan for any Year, Seller
shall also set out in its proposal its estimate of the amount of reasonable operating costs that
would result as a consequence of not making such expenditure. If the Mine Operating Committee votes
to reject the expenditure for such Capital Asset and Seller disagrees with such rejection, then
Seller may submit the decision regarding the Capital Asset to the Executive Committee for review.
If the Buyers’ representatives on the Executive Committee do not unanimously approve such
expenditure, then such expenditure shall not be included in any Approved Annual Operating Plan for
such Year. In such case, neither Seller nor any Buyer may dispute such Executive Committee action
or decision pursuant to subsection 8.3 of this Agreement. If the expenditure for the Capital Asset
is not approved (either by the Buyers’ representatives on the Executive Committee, or by action of
the Mine Operating Committee when Seller does not take the matter to the Executive Committee), the
Operating Budget component of the Annual Operating Plan for such Year and subsequent Years shall be
adjusted to reflect the reasonable increased operating costs that are the consequence of not
acquiring the Capital Asset. Neither Seller nor Buyers may dispute such adjustment to the Operating
Budget pursuant to subsection 8.3 of this Agreement. The Parties further agree that acquisition of
a Capital Asset by Seller or lease of a Capital Asset by Seller pursuant to a capital lease shall
in either case, if pursuant to the approval processes described in this Agreement, result in

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PAGE 15

 

inclusion of the Capital Asset within the Investment Base or Intangible Capital Investment, as the
case may be. Lease of an asset by Seller pursuant to a Qualified Operating Lease shall not result
in inclusion of such asset within the Investment Base or Intangible Capital Investment. The rental
and other amounts payable under the terms of a Qualified Operating Lease shall be operating costs
for purposes of the Operating Budget component of the Annual Operating Plan. Unless the Parties
otherwise mutually agree, no Approved Annual Operating Plan shall contemplate an equipment
operating lease that is not a Qualified Operating Lease.

     7.5. Development of Annual Incentive Fee Plan Component.

     Seller and the Mine Operating Committee shall develop an “Annual Incentive Fee Plan” component
of the Annual Operating Plan which incorporates performance standards and assigns
weight to each standard. In developing the Annual Incentive Fee Plan, Seller and the Mine
Operating Committee shall use their best efforts to achieve all of the following goals:

	 	(a)	 	To reward Seller for:
	 
	 	 	 	(i) proposing an Annual Operating Plan that results in the production
of power by Units 3 & 4 at the lowest practical cost consistent with
Merchant Plant Practice and this Agreement;
	 
	 	 	 	(ii) proposing changes to an Approved Annual Operating Plan that
result in the production of power by Units 3 & 4 at the lowest
practical cost consistent with Merchant Plant Practice and this
Agreement;
	 
	 	 	 	(iii) implementing the Approved Annual Operating Plan;
	 
	 	 	 	(iv) adhering to the Approved Operating Budget;
	 
	 	 	 	(v) adhering to the Approved Capital Budget;
	 
	 	 	 	(vi) achieving high productivity in relation to similarly situated
mines in the coal industry;
	 
	 	 	 	(vii) appropriately mining to achieve coal quality targets set forth
in the Approved Annual Operating Plan;
	 
	 	 	 	(viii) achieving the Mine safety goals set forth in the Environmental
and Safety Plan;
	 
	 	 	 	(ix) achieving the goals set forth in the Personnel Plan;
	 
	 	 	 	(x) achieving environmental and regulatory compliance at the Mine;
	 
	 	 	 	(xi) achieving least-cost coal production, procurement and delivery
consistent with Merchant Plant Practice and this Agreement;

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	 	 	 	(xii) accurate budget forecasting; and
	 
	 	 	 	(xiii) effectively managing Outside Coal Commitments, if any.
	 
	 	(b)	 	To enable Seller to benefit from cost savings
and mining efficiencies;
	 
	 	(c)	 	To measure fairly Seller’s performance against
appropriate industry benchmarks;
	 
	 	(d)	 	To provide Seller with a reasonable opportunity
to earn the entire Incentive Fee Per Ton;
	 
	 	(e)	 	To give Seller a fair incentive to meet the
performance standards contemplated by this subsection; and
	 
	 	(f)	 	To provide flexibility to address changes in
the Approved Annual Operating Plan required by law or by the operation
of Units 3 & 4 and to address material changes in the quantities of
coal required by Buyers (to the extent that these changes are not
caused by Seller’s action or inaction).

     The Parties intend that provisions (a) through (f) of this subsection 7.5 will enable the Mine
Operating Committee and Seller to tailor the Annual Incentive Fee Plan to meet changing
circumstances at the Mine, at Units 3 & 4 and in the coal mining and electric generation
industries. The Parties further intend that provisions (a) through (f) of this subsection 7.5 apply
to matters within Seller’s control, and not to events or circumstances beyond Seller’s control,
including, without limitation, deviations to the Approved Annual Operating Plan requested by the
Mine Operating Committee, rejection of expenditure for a Capital Asset proposed by Seller, or
deviations from an Approved Annual Operating Plan required by changes in law. The Parties do not
intend to use provisions (a) through (f) to ratchet the criteria each Year so that Seller has no
realistic opportunity to earn in full the Incentive Fee Per Ton; rather, the Parties intend to use
provisions (a) through (f) to structure the Annual Incentive Fee Plan to give Seller a fair
incentive to meet the performance standards contemplated by this subsection 7.5. Seller and the
Mine Operating Committee shall reevaluate performance standards and weightings on an annual basis
in the review of the Annual Operating Plan.

     7.6. Decisions on Annual Operating Plan.

     An Annual Operating Plan shall be approved only on the affirmative vote of Buyers owning in
the aggregate not less than eighty-five percent (85%) of the Capacity. In the absence of an
Approved Annual Operating Plan at the commencement of a Year and pending resolution of any
resulting dispute under Section 8 of this Agreement, the Executive Committee may determine by
unanimous agreement the interim Annual Operating Plan to implement. In the
absence of such agreement, (a) if the only matter in dispute involves the Annual Incentive Fee
Plan component of the Annual Operating Plan, the remainder of the Annual Operating Plan that is
undisputed shall be implemented pending such resolution, or (b) if the matter in dispute involves
any component of the Annual Operating Plan other than the Annual Incentive Fee Plan

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component, Seller shall mine coal from Area C in accordance with the provisions of the then expired Approved
Annual Operating Plan describing the quarterly sequence for mining in Area C for Year Two (as
referenced in subsection 7.2(a)), including the cost estimates for such Year Two quarterly mine
sequences described in such plan for the then current Year; provided, however, that
if the disputed matter involves capital expenditures, such matter shall be deemed resolved in favor
of not incurring the capital expenditure(s), and the Operating Budget component shall be
appropriately, adjusted to take into account such deemed decision, pending resolution of which
Annual Operating Plan is adopted as the Approved Annual Operating Plan for the then current Year.
In the absence of direction from the then expired Approved Annual Operating Plan and this
subsection 7.6, Seller shall operate and maintain Area C in accordance with reasonable operating
practices consistent with Merchant Plant Practice and this Agreement.

     7.7. Revisions to the Approved Annual Operating Plan.

     The Parties intend that an Approved Annual Operating Plan may be revised as provided in this
subsection 7.7 to account for changes in circumstances from those anticipated when such plan was
approved.

          7.7.1. Revisions resulting from material changes.

     If an unanticipated material change in circumstances, as described in this subsection 7.7.1,
occurs, either Seller or any Buyer may at any time propose that the Approved Annual Operating Plan
be revised by submitting such proposed revision in writing to each member of the Mine Operating
Committee, and to Seller if the revision is proposed by a Buyer. For the purposes of this
subsection 7.7.1, to be material a change in circumstances must meet one of the following criteria:

	 	(a)	 	The change requires a revision to an Approved
Annual Operating Plan to comply with law or Merchant Plant Practice;
	 
	 	(b)	 	The change involves a variance (positive or
negative) in the total tonnage of coal anticipated to be delivered to
Buyers for the Year which is greater than or equal to [**] percent (
[**]%) of the tonnage for the Year reflected in the Approved Annual
Operating Plan; or
	 
	 	(c)	 	The change involves a variance in the average
Variable Charge per ton for coal to be delivered for the Year which is
greater than or equal to [**] percent ( [**]%) of the average Variable
Charge per ton reflected by the Approved Annual Operating Plan.

     The date on which the proposed revision to the Approved Annual Operating Plan is submitted to
each member of the Mine Operating Committee shall be considered the “Submission Date.” The Mine
Operating Committee and Seller shall meet to consider changes and to approve or disapprove the
revision to the Approved Annual Operating Plan no later than thirty (30) days after the Submission
Date. Seller and the Mine Operating Committee shall approve a revision to an Approved Annual
Operating Plan if it constitutes the most practical cost-effective plan for conforming to Merchant
Plant Practice and this Agreement in the

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circumstances. A proposed revision to an Approved Annual
Operating Plan submitted by Seller shall be approved only on the affirmative vote of Buyers owning
in the aggregate not less than eighty-five percent (85%) of the Capacity. A proposed revision to an
Approved Annual Operating Plan submitted by one or more Buyers shall be approved only (i) with the
approval of Seller plus (ii) the affirmative vote of Buyers owning in the aggregate not less than
eighty-five percent (85%) of the Capacity. If a revision proposed pursuant to this subsection 7.7.1
is not so approved within fifty (50) days after the Submission Date, any Party may require the
dispute be submitted for resolution pursuant to subsection 8.1 below. During the pendency of any
such dispute resolution, Seller shall continue to operate and maintain the Mine in accordance with
the existing Approved Annual Operating Plan, except to the extent required otherwise by law or to
address an emergency pursuant to subsection 7.9.

          7.7.2. Other proposed revisions to an Approved Annual Operating Plan.

     Either Seller or any Buyer may at any time propose that the Approved Annual Operating Plan be
revised for any reason other than those set out in subsection 7.7.1 by submitting the proposed
revision in writing to each member of the Mine Operating Committee, and to Seller if the revision
is proposed by a Buyer. The Seller and the Mine Operating Committee shall address such proposed
revision in a timely manner. A proposed revision to an Approved Annual Operating Plan submitted by
Seller shall be approved only on the affirmative vote of Buyers owning in the aggregate not less
than eighty-five percent (85%) of the Capacity. A proposed revision to an Approved Annual Operating
Plan submitted by one or more Buyers shall be approved only (i) with the approval of Seller plus
(ii) the affirmative vote of Buyers owning in the aggregate not less than eighty-five percent (85%)
of the Capacity. If a revision proposed pursuant to this subsection 7.7.2 is not so approved, no
Party shall be entitled to submit the dispute for resolution pursuant to subsection 8.1 or
otherwise.

     7.8. Reporting on Approved Annual Operating Plan.

	 	(a)	 	For any Capital Asset included in the Approved
Capital Budget which has a budgeted cost in excess of $500,000, Seller
shall provide the Mine Operating Committee with a copy of the
successful bid(s) for such Capital Asset before Seller executes a
contract, purchase order, or other written binding obligation for such
Capital Asset, so that the Mine Operating Committee may, within fifteen
(15) days after receipt thereof, verify that the total cost of the
Capital Asset as reflected in such bid(s) is not or is not likely to be
more than ten percent (10%) over the budgeted cost, and provide final
approval, for acquisition of such Capital Asset; provided,
however, (1) if the total cost of the Capital Asset as
reflected in such bid(s) is less than or equal to the budgeted cost of
such Capital Asset as set forth in the Approved Annual Operating Plan,
the Mine Operating Committee shall be deemed to have provided such
verification and final approval, and (2) if the total cost of the
Capital Asset as reflected in such bid(s) is greater than the budgeted
cost of such Capital Asset as set forth in the Approved Annual
Operating Plan, then if the Mine Operating

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	 	 	 	Committee does not approve
the acquisition or fails to act within such fifteen (15) day period,
the matter shall be deemed to be in dispute and shall be submitted to
the Executive Committee for resolution of such dispute. In the event
the Executive Committee is unable to resolve the dispute, the Capital
Asset shall be deemed rejected as described in subsection 7.4, the
matter shall not be subject to further dispute resolution, and the
Operating Budget component of the Approved Annual Operating Plan for
the Year in question and subsequent Years shall be adjusted to reflect
the reasonable increased operating costs that are the consequence of
not acquiring the Capital Asset.
	 
	 	(b)	 	In addition to other reports Seller is required
to provide under this Agreement, Seller shall provide the following
reports to the Mine Operating Committee: (i) monthly budget variance
reports that show budget-to-actual expenditures for the preceding
month, for both the Approved Capital Budget and the Approved Operating
Budget; and (ii) quarterly budget projection reports that show
projected expenditures versus budgeted amounts for the following
quarter, for both the Approved Capital Budget and the Approved
Operating Budget. Such reports shall keep the Mine Operating Committee
notified of Seller’s performance and of any anticipated
departures for the Year from the Approved Capital Budget, or any
anticipated departure for the Year from the Approved Operating
Budget. Seller shall promptly propose a revision to the Approved
Annual Operating Plan under subsection 7.7 when the anticipated
departure from the Approved Capital Budget exceeds ten percent (10%)
or the anticipated departure from the Approved Operating Budget
exceeds five percent (5%), and the Mine Operating Committee shall use
best efforts to review, modify and approve or disapprove the proposed
revision to the Approved Annual Operating Plan as promptly as
possible in accordance with subsection 7.7. The revised Approved
Annual Operating Plan shall thereafter govern for reporting purposes.
Disputes concerning a proposed revision to an Approved Annual
Operating Plan shall be resolved as provided in subsections 7.7.1 and
8.1.
	 
	 	(c)	 	In the event that Seller fails to notify the
Mine Operating Committee in a timely manner of any anticipated
departures for the Year from the Approved Capital Budget, or any
anticipated departure for the Year from the Approved Operating Budget,
and to promptly propose a revision to the Approved Annual Operating
Plan under subsection 7.7 when the anticipated departures exceed ten
percent (10%) and five percent (5%) respectively, and the cost of coal
to Buyers exceeds the Approved Operating Budget for such Year by more
than ten percent (10%), then the aggregate Earned Portion of the
Incentive Fee Per Ton for such Year shall be

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	 	 	 	reduced on a dollar for
dollar basis by the difference between the cost of coal to Buyers and
one hundred ten percent (110%) of the Approved Operating Budget
(adjusted as appropriate to account for expenditures required by
changes in law not reasonably anticipated at the time of the approval
of the Approved Operating Budget for such Year and to account for
changes in Buyers’ requirements for coal for such Year if such
requirements vary by more than ten percent (10%) from the projections
included in such Approved Operating Budget).

     7.9. Emergency.

     Notwithstanding any other provision of this Agreement, if an emergency threatens life, limb or
property or the safety, integrity or operability of the Mine or requires immediate action in order
to comply with laws, orders, rules or regulations, Seller may take such action whether or
not consistent with the Approved Annual Operating Plan as in its sole discretion, reasonably
exercised, it may deem prudent or necessary to end the emergency; the Parties intend, however, that
Seller will not invest in Capital Assets to respond to any such emergency. Seller shall notify
Buyers promptly of any such action with all relevant details associated therewith and with the
costs incurred as a result of the emergency. The Approved Annual Operating Plan shall automatically
be revised to include all costs for which Seller is entitled to reimbursement pursuant to this
subsection 7.9.

8. RESOLUTION OF DISPUTES

	 	8.1.	 	Failure to Approve an Annual Operating Plan, Approve a Proposed Revision to an
Approved Operating Plan or Agree Upon the Earned Portion of the Incentive Fee Per Ton.

     If (a) the Mine Operating Committee does not approve a proposed Annual Operating Plan by
September 1, as required by subsection 7.3, (b) the Seller and the Mine Operating Committee do not
approve a proposed revision to an Approved Annual Operating Plan, by the time specified in
subsection 7.7.1, or (c) Seller and the Mine Operating Committee are unable to agree on the Earned
Portion of the Incentive Fee Per Ton for a Year by March 1 of the subsequent Year, then any Party
may by notice to the other Parties require that the Executive Committee meet to resolve the dispute
within a further thirty (30) days. Seller and the Mine Operating Committee may each present its
position to the Executive Committee and may support its position with reports prepared by
consultants. Any Buyer may submit to the Executive Committee its own statement in support of the
position of Seller or of the Mine Operating Committee. If the Executive Committee does not resolve
the dispute by unanimous agreement within the further thirty (30) day period and (a) the dispute is
with respect to the determination of the Earned Portion of the Incentive Fee Per Ton, Seller and
the Mine Operating Committee (based upon a vote of the Buyers pursuant to subsection 6.2) shall
each within a further five (5) business days give all Parties notice of a final proposed Earned
Portion of the Incentive Fee Per Ton; and either Seller or the Buyers acting through the Mine
Operating Committee may thereafter submit the dispute to arbitration pursuant to subsection 8.3
below; or (b) the dispute is with respect to an Annual Operating Plan or revision to an Approved
Annual Operating Plan, Seller’s representative

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on the Executive Committee and each Buyer’s
representative on the Executive Committee (individually or as part of a group of Buyers) shall give
the other Parties notice of a final proposed Annual Operating Plan or revision to the Approved
Annual Operating Plan, as the case may be; and any Party may then submit the dispute to arbitration
pursuant to subsection 8.3 below. If the dispute involves an Annual Operating Plan, each of Seller
and Buyers (individually or collectively, as they may severally choose) shall submit in such
arbitration both its proposed Annual Operating Plan and a document setting forth why the arbitrator
should adopt that Party’s plan as opposed to any other Party’s plan, including how operations would
be affected if the
other Party or Parties prevail(s) on the disputed item, such that the arbitrator comprehends
such Party’s position with respect to the impact on the Annual Operating Plan both if such Party
prevails and if such Party does not prevail on the disputed matter(s).

     8.2. Disputes Regarding Cost Charges Other Than Earned Portion of the Incentive Fee Per Ton.

     If the Parties to a dispute regarding any costs charged under this Agreement, other than the
Earned Portion of the Incentive Fee Per Ton, are unable to resolve the dispute, any Party involved
in the dispute may by written notice to the other involved Parties require that each of such
Parties designate a representative with authority to resolve the dispute, and that the
representatives of such Parties meet to resolve the dispute within thirty (30) days. If the
representatives are unable to resolve the dispute within the thirty (30) day period, Seller’s
representative and either (i) the Mine Operating Committee (based upon a vote of the Buyers
pursuant to Section 6.2) if the cost in dispute applies to all of the Buyers and all of the Buyers
choose to dispute the cost, (ii) the representatives (acting jointly) of multiple but less than all
of the Buyers if the cost in dispute is disputed by multiple but less than all of the Buyers or
(iii) the representative of the affected Buyer if the cost in dispute applies only to an individual
Buyer or only one Buyer chooses to dispute the cost, shall within a further five (5) business days
give all Parties involved in the dispute notice of a proposed final resolution of the dispute.
Seller, the Buyers acting through the Mine Operating Committee with respect to cost disputes
affecting the Buyers as a group, multiple but less than all Buyers acting through their
representatives (acting jointly) with respect to cost disputes disputed by multiple but less than
all Buyers, or an individual Buyer with respect to cost disputes affecting an individual Buyer, may
then submit the resolution of the dispute to arbitration under subsection 8.3.

     8.3. Arbitration Process.

     Each arbitration under this Section 8 shall be before one neutral arbitrator selected
unanimously by the Executive Committee; if the Executive Committee is unable to agree unanimously
upon the selection, then the arbitrator shall be selected in accordance with the Commercial Rules
of the American Arbitration Association. For disputes described in subsection 8.1, the arbitrator
shall be (i) recognized as knowledgeable regarding the western surface coal mining industry, (ii)
neither an employee (or retired or previous employee) of any Party, nor a person with any
substantial relationship with any Party, nor a person having any financial or professional interest
in the outcome of the arbitration and (iii) experienced in evaluating mining plans for surface coal
mines. For disputes described in subsection 8.2, the arbitrator shall be (i) recognized as
knowledgeable regarding cost accounting in the western surface coal mining industry, and (ii)
neither an employee (or retired or previous employee) of any Party, nor a

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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person with any
substantial relationship with any Party, nor a person having any financial or
professional interest in the outcome of the arbitration. The arbitration shall be held in
Denver, Colorado pursuant to the Expedited Procedures of the Commercial Rules and the arbitrator
shall render a decision by using “last best offer arbitration.” In the event the selected
arbitrator fails to issue his or her decision within sixty (60) days of his or her selection, such
arbitrator shall be replaced immediately at the request of any Party to the arbitration. In the
case of an arbitration pursuant to subsection 8.1 regarding approval of an Annual Operating Plan or
a proposed revision to an Approved Annual Operating Plan, the arbitrator shall approve only one of
the proposed Annual Operating Plans or revisions by determining which proposed final resolution of
the dispute is the most practical cost-effective plan for conforming with Merchant Plant Practice
and this Agreement in the circumstances. The Annual Operating Plan approved by the arbitrator shall
constitute the Approved Annual Operating Plan for the Year in question. In the case of an
arbitration under subsection 8.1 regarding the Earned Portion of the Incentive Fee Per Ton for a
Year, the arbitrator shall approve only one of the proposed Earned Portion of the Incentive Fees
Per Ton by determining which of the two proposed final resolutions of the dispute most closely
reflects Seller’s performance relative to the Annual Incentive Fee Plan for the subject Year. In
the case of an arbitration under subsection 8.2 involving a dispute regarding costs charged under
this Agreement, the arbitrator shall approve only one of the two proposed final resolutions for
each such dispute by determining which proposed final resolution most closely comports with this
Agreement. Seller and the Buyers collectively (with each Buyer bearing a proportionate part of the
Buyers’ collective share of such fees and expenses in accordance with such Buyer’s proportionate
ownership of Capacity) shall each bear one-half of all fees and expenses of any arbitration under
this subsection 8.3 involving the Mine Operating Committee and Seller, and Seller and any
individual Buyers) shall, respectively, each bear one-half of all fees and expenses of any
arbitration involving a cost dispute affecting only that individual Buyer(s); however, each Party
shall bear the expenses of its own counsel, experts, witnesses, and preparation. Judgment may be
entered upon the arbitrator’s award in any court having jurisdiction; provided,
however, any such award which does not conform to the “last best offer” form of arbitration
contemplated by this subsection 8.3 shall be invalid and of no effect, and the dispute related
thereto shall be resubmitted to arbitration consistent with the requirements of this subsection
8.3.

8.4. Resolution of Other Disputes.

     Those disputes described in subsections 8.1, 8.2, 12.6, 12.7, 15.2.D. and subsection 3.5(c) of
Exhibit B hereto, but only such disputes, shall be resolved exclusively by arbitration under
subsection 8.3. In addition, (i) the exclusive and final mechanism for resolution of the accounting
issues identified at subsections 12.3.2 and 12.5.5 shall be through the use of an independent
accounting firm as described in those provisions, (ii) the exclusive and final mechanism for
resolution of disputes involving coal analysis shall be the use of an independent commercial
laboratory as described in Section 11, (iii) the exclusive and final mechanism for resolution of
disputes involving acquisition of Capital Assets shall be as set forth in subsection 7.4 and (iv)
the exclusive and final mechanism for resolution of disputes under subsection 15.3(d) shall be as
described in subsection 15.3(d). All other disputes may be resolved as permitted by law, subject
only to the conditions precedent that (i) any complaining party shall first bring its dispute to
the attention of the Executive Committee by written notice to its members which shall meet to
resolve the dispute within a further thirty (30) days and (ii) if not resolved by the Executive

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Committee, then the complaining Party shall first offer to submit the matter to non-binding
mediation for a period of sixty days and participate in good faith in such mediation.

9. DELIVERY, WEIGHING AND TRANSPORTATION

     9.1. Point of Delivery.

     The coal sold hereunder shall be delivered to Buyers at the western end of the coal conveyor
system utilized for the transportation of coal from Area C to Units 3 & 4 (“Point of Delivery”).

     9.2. Weight and Scales.

     All coal delivered hereunder shall be weighed by Seller at the Point of Delivery, and these
weights shall be used for billing purposes. Scales to be used for weighing shall be calibrated at
such frequency as is required or recommended by Western Weighing and Inspection Bureau and using
Western Weighing and Inspection Bureau standards. Buyers, at their sole expense, may have a
representative present to observe any testing, calibration or certification of the scales. If upon
calibration the scales are found to be in error or inaccurate by one percent (1 %) or more, the
scales shall be recalibrated for future shipments, the Parties shall use their best efforts to
estimate the correct amount of coal delivered during the period affected by such error or
inaccuracy by the best available means, and any appropriate adjustments shall be made. Buyers may
inspect Seller’s weighing facilities and may make such verification of accuracy of weights as
Buyers deem necessary.

     9.3. Scheduling Deliveries.

     Consistent with the Approved Annual Operating Plan, Seller and Buyers shall cooperate in
scheduling daily and monthly coal deliveries in order to accommodate Buyers’ changing fuel
requirements. The Parties shall also cooperate in the same manner in notifying each other in
advance of scheduled outages or downtime in order to avoid unnecessary inconvenience and delay and
to facilitate efficient use of said downtime by each Party and to the extent reasonably possible to
assure Buyers of an opportunity to increase their stock pile of coal for use during downtime at the
Mine. Subject to these reciprocal obligations, Seller shall maintain the capability of making
continuous coal deliveries to Buyers within the design limitations of Buyers’ coal
receiving facilities. During any period in which Seller is for any reason unable to supply
coal from Area C at a rate of delivery sufficient to sustain Units 3 & 4 generation at the level
desired by Buyers, Seller shall use its best efforts to supply an amount of coal up to 60,000 tons,
as designated by Buyers, to Units 3 & 4 from other areas of the Mine. If Seller is unable to supply
such 60,000 tons of coal from other areas of the Mine so as to achieve such rate of delivery, then
Seller shall pay the reasonable costs incurred by Buyers in taking coal from Buyers’ dead storage
and replacing the same amount in such dead storage. Seller’s obligation to pay such costs shall be
limited for any single delivery interruption to payments with respect to 60,000 tons, less all tons
delivered to Buyers from areas of the Mine other than Area C during such interruption.

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10. QUALITY

     10.1. Applicable to Coal from Seller’s Mine.

     This Section 10 shall be applicable to coal delivered by Seller from Area C, and shall not be
applicable to coal delivered by Seller from outside sources other than Area C.

     10.2. Coal Specifications.

     The coal sold and delivered hereunder shall be [**] inch size and no pieces shall be larger
than [**] inches in any dimension. The coal shall be unwashed, undried and untreated by oil or
other chemical agents, unless such additional preparation is mutually agreed upon. The coal shall
be from the Rosebud seam or shall be coal of equivalent quality. Buyers recognize that coal sold
and delivered hereunder has inherent qualities which cannot be changed, but Seller shall make all
reasonable efforts to produce coal which has the average quality represented in subsection 10.3 and
shall be generally free of overburden, underclay and other nonintrinsic material which can be kept
out or removed by exercising reasonable care during mining, processing and loading of the coal.

     10.3. Average Coal Quality and Characteristics.

     The coal is sub-bituminous and as delivered to Units 3 & 4 shall have average quality and
characteristics approximately as follows:

ROSEBUD SEAM

COAL ANALYSIS

On As-Received Basis

	 	 	 	 	 
	      Proximate Analysis
	Component	 	% By Weight
	Moisture
	 	 	[**]	 
	Volatile Matter
	 	 	[**]	 
	Fixed Carbon
	 	 	[**]	 
	Ash
	 	 	[**]	 
	 
	 	 	 	 
	Total
	 	 	100.00	 

	 	 	 	 	 
	      Ultimate Analysis
	Component	 	% By Weight
	Carbon, C
	 	 	[**]	 
	Hydrogen, H2
	 	 	[**]	 
	Sulfur, S
	 	 	[**]	 
	Oxygen, 02
	 	 	[**]	 
	Nitrogen, N2
	 	 	[**]	 
	Moisture, H20
	 	 	[**]	 
	Ash
	 	 	[**]	 
	 
	 	 	 	 
	Total
	 	 	100.00	 

Btu/lb.                                    [**]

Grindability Index (Hardgrove)                [**]

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Ash Fusion Temperature, °F

	 	 	 	 	 
	      Oxidizing	 	 	 	 
	Initial Deformation
	 	 	[**]	 
	Softening (H+W)
	 	 	[**]	 
	Softening (H=1/2W)
	 	 	[**]	 
	Fluid
	 	 	[**]	 

	 	 	 	 	 
	      Reducing	 	 	 	 
	Initial Deformation
	 	 	[**]	 
	Softening (H+W)
	 	 	[**]	 
	Softening (H=1/2W)
	 	 	[**]	 
	Fluid
	 	 	[**]	 

     10.4. Minimum and Maximum Characteristics.

     Buyers and Seller agree that the coal to be delivered from Area C under this Agreement shall
be mine-run coal and will fluctuate as to quality and characteristics; however, Seller guarantees
that the coal shall not be less than the minimum nor more than the maximum specifications
following:

	 	 	 	 	 
	Characteristic	 	Specification
	Maximum moisture content (as received)
	 	 	[**]	%
	Maximum ash content (as received)
	 	 	[**]	%
	Maximum sulfur content (as received)
	 	 	1.5	%
	Minimum ash fusion temperatures,
°F in reducing atmosphere:
	 	 	 	 
	Initial Deformation
	 	 	[**]	 
	Softening
	 	 	[**]	 
	Fluid
	 	 	[**]	 
	Minimum Grindability (Hardgrove)
	 	 	[**]	 
	Minimum Btu/lb. (as received)
	 	 	[**]	 

     10.5. Nonconforming Coal.

     Except as may be specified otherwise in the Approved Annual Operating Plan, should the coal as
received fail to conform to the minimum or maximum specifications set forth in subsection 10.4 when
calculated as a weighted average over a thirty (30) day period, Buyers may suspend acceptance of
any further shipments of such coal hereunder until they receive reasonable assurance from Seller
that future deliveries will conform to the specifications. During such

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suspension period, Seller
shall supply Buyers with the quality and quantity of coal agreed upon herein from other sources at
no increased cost to Buyers.

11. SAMPLING AND ANALYSIS

     At least one representative sample from each twenty-four (24) hours of coal deliveries
hereunder shall be taken by Operator using Buyers’ sampling equipment. Buyers and Seller shall have
the right to have a representative present at any and all times to observe the sampling. An
independent third party testing laboratory unanimously selected by Buyers and Seller shall assure
the integrity of the samples taken as consistent with American Society for Testing Materials
(“ASTM”) standards. Such independent third party testing laboratory shall ensure that all samples
are divided into not less than four (4) parts and put in suitable airtight containers, the second,
third and fourth containers to be held available by the testing laboratory for a period of ninety
(90) days after the end of the calendar month in which such sample was taken. The independent third
party testing laboratory shall analyze the first part. Buyers and Seller may analyze at their own
sole expense the second and third parts, respectively. The fourth part shall be for analysis if a
dispute arises regarding the independent laboratory’s initial analysis. All sampling and analysis
shall be performed in accordance with ASTM standards unless other methods are agreed upon
unanimously by Buyers and Seller. Buyers and Seller shall each receive from the independent
laboratory a copy of the report of each analysis. If no Party takes exception to the independent
laboratory’s analysis within sixty (60) days after receipt of the report, the laboratory’s analysis
shall be deemed conclusive. If any Party takes exception to the laboratory analysis, the dispute
shall be referred to a commercial testing laboratory selected by the disputing Parties. The results
of such commercial testing laboratory analysis shall be controlling and shall not be subject to
further review. The cost of the analysis made by such latter commercial laboratory shall be shared
equally between Seller and Buyers.

12. PRICE AND PAYMENT

     12.1. Determination of Price.

     For the period prior to July 1, 2000, the Price to be paid by Buyers for coal delivered by
Seller hereunder from Area C shall be determined in accordance with Exhibit B. Commencing
July 1, 2000 and continuing through December 31, 2019, the Price to be paid by Buyers for coal
delivered by Seller hereunder from Area C shall be as provided in this Section 12.

     12.2. Price Components.

     The Price for coal delivered by Seller hereunder from Area C on and after July 1, 2000 shall
be on a cost-plus basis where Buyers pay their proportionate share of actual labor and other costs
following a least-cost mine plan as reflected in the Approved Annual Operating Plan. The Price
shall be the price per ton computed from the sum of Fixed Costs, as defined in subsection 12.3, and
the Commodity Charge. The “Commodity Charge” shall include the Variable Charge, ROI, Fixed Fee Per
Ton, Incentive Fee Per Ton and Royalties and Production Taxes, all as defined and determined
pursuant to subsections 12.4, 12.5, 12.6, 12.7 and 12.8 below. No cost or credit in one component
of Price shall be duplicated in another component of Price. Such Price is f.o.b. the Point of
Delivery.

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     12.3. Fixed Costs.

     “Fixed Costs” shall be equal to the actual costs for the Year for:

	 	(a)	 	[**]or other [**] to [**]hereunder to [**];
	 
	 	(b)	 	[**]on [**];
	 
	 	(c)	 	all costs of [**];
	 
	 	(d)	 	[**];
	 
	 	(e)	 	[**];
	 
	 	(f)	 	[**]costs for [**]and [**]; and
	 
	 	(g)	 	appropriate administrative & general (“A&G”)
expenses, including [**]and [**]for [**]and [**]the Mine, whether
[**]the Mine.

          12.3.1. Depreciation rates.

     Depreciation rates shall be determined by Seller from time to time using [**] methods over
the useful economic life of the assets and shall otherwise be consistent with generally accepted
accounting principles as applied to the surface coal mining industry as determined by Seller’s
independent auditors.

          12.3.2. A&G expenses.

     A&G expenses shall reflect an appropriate apportionment to Units 3 & 4 of the reasonable and
necessary administrative & general expenses for the entire Mine. Buyers and Seller agree to engage
an independent accounting firm to determine in 1998:

	 	(a)	 	The appropriate administrative & general
expense accounts for operating the Mine as a whole;
	 
	 	(b)	 	Whether the amounts of Seller’s administrative
& general expenses are reasonable in amount; and
	 
	 	(c)	 	Fair allocation mechanisms to apportion
reasonable administrative & general expenses for the Mine to Units 3 &
4 and between the coal supply to the Point of Delivery and the coal
transportation from the Point of Delivery to Units 3&4.

     The independent accounting firm’s determinations of the foregoing issues shall be the basis
for determining A&G expenses applicable to Units 3 & 4 subsequent to June 30, [**].

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          12.3.3. Payment of Fixed Costs.

     For the period July 1, 2000 through December 31, 2000, Fixed Costs shall be paid initially in
monthly installments at the rate of one-sixth (1/6) of the amount estimated for such six months in
the Approved Operating Budget described in subsection 7.2 above. Thereafter, Fixed Costs shall be
paid initially in monthly installments at the rate of one-twelfth (1/12) of the amount estimated
for the Year pursuant to the Approved Operating Budget described in subsection 7.2 above. Within
forty-five (45) days after the end of each Year, Seller shall provide Buyers a calculation of the
actual Fixed Costs for the Year and debit or credit Buyers for the difference between the estimated
and actual Fixed Costs. Among the Buyers, responsibility for Fixed Costs shall be allocated on the
basis of their percentage ownership of Capacity.

     12.4. Variable Charge.

     The “Variable Charge” shall be a per ton charge equal to the actual variable costs directly
incurred in mining and delivering each ton of coal to the Point of Delivery. These variable costs
include:

	 	(a)	 	[**]costs, including [**]and [**]and [**];
	 
	 	(b)	 	[**];
	 
	 	(c)	 	[**]and [**]or [**]in the [**]or [**];
	 
	 	(d)	 	Costs for [**]and [**] in connection with
[**]and [**]of [**] and [**] ;
	 
	 	(e)	 	Costs of [**] ;
	 
	 	(f)	 	[**] and [**] if [**] or [**] or [**] ;
	 
	 	(g)	 	[**] of [**] on [**] ; and
	 
	 	(h)	 	Costs of [**] and, with respect to [**] if any
[**] in [**] with [**] .

          12.4.1. Imported or exported equipment.

     In no event shall any of the following costs be included in the Variable Charge or otherwise
allocated to Buyers: (i) costs incurred in connection with moving any equipment out of or returning
to Area C in connection with the use of such equipment outside of Area C; or (ii) any operating
costs allocable to the operation of equipment outside of Area C. If Seller uses any equipment that
is dedicated to a mining area other than Area C to produce coal in Area C for delivery to Buyers
under this Agreement, Buyers shall pay as part of the Variable Charge the reasonable costs incurred
in connection with moving such equipment into and out of Area C and the operating costs allocable
to the operation of such equipment in Area C, all multiplied by the number of tons of coal produced
in Area C for delivery to Buyers under this Agreement using such equipment, and divided by the
total number of tons of coal produced in Area C using such equipment.

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          12.4.2. Payment of Variable Charge.

     The Variable Charge shall be paid initially based on the per ton estimate of variable costs
for the calendar year developed pursuant to the Operating Budget described in subsection 7.2 above.
Within forty-five (45) days after the end of each calendar quarter, Seller shall provide Buyers a
calculation of the actual variable costs described above in this subsection 12.4 for the calendar
quarter and debit or credit Buyers for the difference between the estimated and actual variable
costs of providing coal to Buyers under this Agreement. The debit or credit applied to each
individual Buyer shall be a direct function of the ratio of the tons taken by such Buyer to the
tons taken by all Buyers under this Agreement.

     12.5. Return on Investment.

     Return on Investment (“ROI”) shall be a per ton charge to provide Seller a return on its
capital investment in Area C, including Area C equipment and including intangibles. ROI shall be
the sum of two values:

	 	(a)	 	The pre-July 1, 2000 ROI rate multiplied by the
pre-July 1, 2000, Investment Base and pre-July 1, 2000, Intangible
Capital Investment; plus
	 
	 	(b)	 	The post-June 30, 2000 ROI rate multiplied by
the post-June 30, 2000, Investment Base and post-June 30, 2000
Intangible Capital Investment.

     The ROI rate to be applied to the pre-July 1, 2000 Investment Base and pre-July 1, 2000
Intangible Capital Investment shall be determined pursuant to subsection 12.5.1, below. The ROI
rate to be applied to the post-June 30, 2000 Investment Base and post-June 30, 2000 Intangible
Capital Investment shall be determined pursuant to subsections 12.5.2 and 12.5.3, below. Investment
Base shall be determined pursuant to subsection 12.5.4, below, and the Intangible Capital
Investment shall be determined pursuant to subsection 12.5.5, below.

          12.5.1. ROI rate for pre-July 1, 2000 investments.

     The ROI rate for investments hereunder made prior to July 1, 2000 shall be a pre-tax rate of
[**] % per annum. Such rate shall not be subject to adjustment for changes in tax rates, and shall
not be subject to adjustment for market changes in the cost of capital until July 1, 2005.
Beginning July 1, 2005, and each July 1 thereafter, the pre-tax ROI of [**] % per annum shall be
adjusted for one half (1/2) the difference (plus or minus) between (a) the arithmetic mean of the
Treasury Bond Rate as of the first day of the month for each of the preceding 60 months and (b) 6%.
(For example, if the five-year monthly rolling average for Treasury Bonds at July 1, 2005 is 4%,
then the [**] % ROI rate would be reduced by one half of 2%, with a resulting ROI rate of [**]
%).

          12.5.2. ROI rate on post-June 30, 2000 investments.

     The ROI rate for tangible or intangible investments made hereunder on or after July 1, 2000,
in lieu of the rate specified in subsection 12.5.1 above, shall be calculated as of the date

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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Seller executes a purchase order or otherwise becomes legally bound to make the capital
investment, following approval for such investment pursuant to subsections 7.3 and 7.4 above. The
full amount by which such then-current Treasury Bond Rate is greater than or less than 6% per
annum, shall be added to or subtracted from, as the case may be, a pre-tax ROI rate of [**] % to
determine the ROI rate applicable to the specific investment.

          12.5.3. Melding of ROI rates for post-June 30, 2000 investments.

     At the end of each Year in which new investments are made after June 30, 2000 pursuant to
subsections 7.3 and 7.4, the ROI rate for investments made in such Year shall be melded with the
ROI rate for previous investments made subsequent to June 30, 2000, on a weighted-average basis to
achieve a new ROI rate for all existing investments. (For example, if the post-June 30, 2000
existing investment as of December 31, 2002 (net of depreciation through such date) is $4 million
at a pre-tax ROI rate of [**] % and $1 million of new investment is made during the current Year
at a pre-tax ROI rate of [**] %, then the melded going forward ROI for post-June 30, 2000 net
investments of $5 million would be [**] %).

          12.5.4. Investment Base.

     “Investment Base” shall be equal to the Area C mine investment made by Seller less (a)
accumulated depreciation and (b) gains on the sale of Capital Assets included in Investment Base
prior to such sale. “Investment Base” shall include a reasonable amount for working capital related
to maintaining parts and warehouse inventory (but not pit inventory); such reasonable amount for
working capital shall be considered a pre-June 30, 2000 investment. (As of January 1, 1998,
Investment Base is approximately $ [**] million; in addition, Seller will dedicate to Area C as of
June 30, 2000 an 8050 dragline with a capital cost of $ [**] million.) Investment Base shall
include expenditures for tangible Capital Assets made by Seller subsequent to January 1, 1999 to
the extent they are made pursuant to an Approved Capital Budget subject to the provisions of
subsections 7.3, 7.4, 7.7 and 7.8. For any Year, Investment Base shall be equal to the average of
the beginning and ending Year balances. (For example, if the pre-July 1, 2000, net investment as of
January 1 of a Year is $ [**] million and the pre-July 1, 2000, net investment as of December 31
of such Year is $ [**] million, then the pre-July 1, 2000, Investment Base for the Year is $ [**]
million.)

          12.5.5. Intangible Capital Investment.

     “Intangible Capital Investment” shall include:

	 	(a)	 	Current intangible capital investment, less
amortization, as of January 1, 1998 of $ [**] million;
	 
	 	(b)	 	Actual costs of intangible capital investment
planned to be made in 1998 for Area C lease acquisition (estimated to
be $ [**] million), if made; and
	 
	 	(c)	 	Any new investments in Capital Assets made by
Seller which are made with the prior approval of the Mine Operating
Committee pursuant to subsections 7.4 and 7.8(a) above, and which are

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	 	 	 	properly classified as intangibles consistent with the determinations
of the independent accounting firm as provided below.

     All charges paid by Buyers for depletion pursuant to subsection 12.4(g) shall be deducted from
all items (a)-(c) above to calculate Intangible Capital Investment. For any Year, Intangible
Capital Investment shall be equal to the average of the beginning and ending Year balances. (For
example, if the net post-June 30, 2000 investment as of January 1 of a Year is $ [**] million and
the net post-June 30, 2000 investment as of December 31 of such Year is $ [**] million, then the
Intangible Capital Investment for the Year is $ [**] million.) Buyers and Seller shall engage the
same independent accounting firm selected pursuant to subsection 12.3.2 to determine in 1998 for
use from and after July 1, 2000:

(i) The appropriate intangible capital investment accounts for
operating Area C;

(ii) Whether the amounts of Seller’s intangible capital investments
are reasonable in amount; and

(iii) Fair allocation mechanisms to apportion reasonable intangible
capital investments to Units 3 & 4.

     The independent accounting firm’s determinations of the foregoing issues shall be made in
accordance with generally accepted accounting principles as applied to the surface coal mining
industry and shall be the basis for determining Intangible Capital Investment applicable to Units 3
& 4.

          12.5.6. Payment of Return on Investment.

     The ROI charge for the period July 1, 2000 through December 31, 2000 shall be paid on a pro
rata basis to the first [**] tons of coal delivered to Buyers on or after July 1, 2000 and shall
be based on the estimated ROI for the last six months of such Year. For each Year subsequent to
2000, the ROI charge shall be paid-on a pro rata basis on the first 5,000,000 tons of coal
delivered that Year to the Buyers, whether delivered to Buyers by Seller or by deliveries of
Outside Coal, and shall be based on the estimated ROI for such Year. Within forty-five (45) days
after the end of each Year, Seller shall provide Buyers a calculation of the actual ROI for the
Year and debit or credit Buyers for the difference between the estimated and actual ROI Among the
Buyers, responsibility for payment of the ROI charge shall be allocated on the basis of their
percentage ownership of Capacity irrespective of the actual purchases of coal by each individual
Buyer.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     12.6. Fixed Fee Per Ton.

     “Fixed Fee Per Ton” shall be a per ton profit charge for each ton of coal delivered by Seller
to Buyers under this Agreement. The Fixed Fee Per Ton charge as of July 1, 2001 shall be $.40 per
ton, and it shall be adjusted every January 1 and July 1 subsequent to July 1, 2001 for inflation
or deflation subsequent to July 1, 2000. To compute new values, the Parties shall use the [**] ,
first published for the three-month period ending July 1, [**] as the base. Expressed
mathematically, the formula is as follows:

FFPT = $.40/ton * (Gx)/(G1)

where:

	 	 	 	 	 	 	 
	 

	 	FFPT
	 	=
	 	Fixed Fee Per Ton, as adjusted
	 
	 	 	 	 	 	 
	 

	 	Gx
	 	=
	 	[**] first published for the three-month period ending the
preceding October 1 (in the case of a January 1 adjustment)
or April 1 (in the case of a July 1 adjustment)
	 
	 	 	 	 	 	 
	 

	 	G1
	 	=
	 	[**] first published for the three-month period ending July
1, [**]

     If the [**] ( [**] ) ceases to be published by the [**] or any other federal agency or is
rebased or otherwise modified, such index shall be replaced by a substantially equivalent index
that, after necessary adjustment, if any, provides the most reasonable substitute for such index
and which is mutually agreeable to Buyers and Seller. If an agreement cannot be reached with ninety
(90) days of discontinuance of such index, then the matter shall be submitted to the Executive
Committee for dispute resolution, and if the Executive Committee does not resolve the dispute
within thirty (30) days thereafter, the matter shall be submitted to binding “last best offer”
arbitration pursuant to subsection 8.3.

     12.7. Incentive Fee Per Ton.

	 	(a)	 	“Incentive Fee Per Ton” shall be a charge for
each-ton of coal delivered by Seller to Buyers under this Agreement in
a Year. The Incentive Fee Per Ton charge shall be $.35 per ton as of
July 1, 2000. The Incentive Fee Per Ton shall thereafter be adjusted
every January 1 and July 1 subsequent to July 1, 2001 for inflation or
deflation subsequent to July 1, 2000. To compute the adjusted Incentive
Fee Per Ton, the Parties shall use the [**] ( [**] ) first published
for the three-month period ending July 1, [**] as the base. Expressed
mathematically, the formula is as follows:

IFPT = $.35/ton * (Gx)/(G1)

where:

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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	 	IFPT
	 	=
	 	Incentive Fee Per Ton, as adjusted
	 
	 	 	 	 	 	 
	 

	 	Gx
	 	=
	 	[**] first published for the three-month period ending the
preceding October 1 (in the case of a January 1 adjustment)
or April 1 (in the case of a July 1 adjustment)
	 
	 	 	 	 	 	 
	 

	 	G1
	 	=
	 	[**] first published for the three-month period ending July

1, [**]

If the [**] ( [**] ) ceases to be published by the [**] or any other federal agency or is
rebased or otherwise modified, such index shall be replaced by a substantially equivalent index
that, after necessary adjustment, if any, provides the most reasonable substitute for such index
and which is mutually agreeable to Buyers and Seller. If an agreement cannot be reached with ninety
(90) days of discontinuance of such index, then the matter shall be submitted to the Executive
Committee for dispute resolution, and if the Executive Committee does not resolve the dispute
within thirty (30) days thereafter, the matter shall be submitted to binding “last best offer”
arbitration pursuant to subsection 8.3.

	 	(b)	 	The Seller shall invoice and be paid the
Incentive Fee Per Ton during the course of the Year. On or before March
1 following each Year, the Mine Operating Committee in consultation
with Seller shall determine Seller’s entitlement to all or any portion
of the Incentive Fee Per Ton for the preceding Year in accordance with
the performance standards and weighting contained in the Annual
Incentive Fee Plan developed under subsection 7.5 of this Agreement.
The amount of such entitlement shall be the “Earned Portion of the
Incentive Fee Per Ton.” The Earned Portion of the Incentive Fee Per Ton
may be any amount from zero to the full Incentive Fee Per Ton, but may
not be more than the Incentive Fee Per Ton, or less than zero (i.e., it
may not be used as a penalty). If Seller and the Mine Operating
Committee are unable to agree on the Earned Portion of the Incentive
Fee Per Ton for a Year by March 1 of the subsequent Year, the Parties
shall utilize the dispute resolution procedure described in subsection
8.1. Subject to any adjustment of the aggregate Earned Portion of the
Incentive Fee per Ton pursuant to subsection 7.8(c), if the Earned
Portion of the Incentive Fee Per Ton is lower than the Incentive Fee
Per Ton payments made by Buyers for the applicable Year, Seller shall
credit the Buyers for the difference multiplied by the number of tons
delivered to the Buyers during such Year, and interest on such
overpayment from July 1 of the applicable Year to the date of payment
at the interest rate specified in subsection 12.13, together with a
credit for taxes and royalties associated therewith.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     12.8. Royalties and Production Taxes.

     Quarterly, Seller shall invoice Buyers separately, and Buyers shall pay, all Royalties and
Production Taxes. However, Buyers shall not be obligated to reimburse Seller for penalties or
interest associated therewith resulting solely from late payments or administrative errors made by
Seller in filing royalty and production tax forms and returns. Unless the Mine Operating Committee
otherwise directs, Seller shall use its best efforts to

(i) obtain credits or refunds for all Royalties and Production Taxes
paid by Buyers that are either (a) associated with charges for coal
that are later credited or refunded by Seller to Buyers, or (b) are
reasonably subject to challenge if it would be prudent under Merchant
Plant Practice to pursue such credits and refunds. Buyers shall
reimburse Seller for all costs incurred to obtain royalty and
production tax refunds. In such event, Buyers shall reimburse Seller
for all costs incurred to obtain such credits or refunds; and

(ii) dispute or contest claims for additional Royalties and/or
Production Taxes. In such event, Buyers shall reimburse Seller for
all costs incurred to dispute or contest such claims, including
related penalties or interest imposed upon and paid by Seller.

     12.9. Invoices.

     Buyers agree to submit to Seller a monthly “Distribution Notice” in a form to be mutually
agreed upon setting forth the portion of actual deliveries during the preceding month to be billed
to each of the Buyers. Invoices will be prepared and submitted by Seller on a calendar month basis
on or before the fifth (5th) calendar day of the following month based upon such Distribution
Notice. Buyers shall make payments monthly, within fifteen (15) calendar days after receipt of
invoice, to Seller at its office at 16 East Granite, Butte, Montana 59701.

     12.10. Credits for Third Party Sales.

	 	(a)	 	If in any Year Seller sells or otherwise
delivers to third parties any coal produced in Area C using any Capital
Equipment, Buyers shall promptly receive a credit towards the payment
of the Fixed Costs and ROI for such Year equal to the number of tons of
coal so sold to third parties, multiplied by the sum of such Fixed
Costs and ROI, and divided by the total tons of coal taken from Area C
in such Year.
	 
	 	(b)	 	If Seller sells or otherwise delivers to third
parties any coal produced in Area C, the actual costs of mining related
to such deliveries shall not be included in the Variable Charge paid by
Buyers pursuant to subsection 12.4.
	 
	 	(c)	 	If in any Year Seller uses any Major Equipment
that is Capital Equipment outside of Area C, Buyers shall promptly
receive a credit towards the payment of the Fixed Costs and ROI for
such Year equal to the number of hours during which such Major

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 35

 

	 	 	 	Equipment was operated outside of Area C during such Year, multiplied
by that portion of the Fixed Costs and ROI for such Year which is
allocable to property taxes, ROI and depreciation expenses and which
is allocable pursuant to generally accepted accounting principles
consistently applied to such Major Equipment, and divided by the
total number of hours such Major Equipment was operated during such
Year. Seller shall use its best efforts to minimize the assignment of
such Major Equipment to areas outside Area C and shall do so only to
the extent permitted pursuant to the Approved Annual Operating Plan.
	 
	 	(d)	 	If in any Year Seller uses any Major Equipment
that is dedicated to a mining area other than Area C (e.g., so that
such Major Equipment is not Capital Equipment or otherwise taken into
account in the determination of Fixed Costs, Commodity Charge or
Investment Base) to produce coal in Area C for delivery to Buyers under
this Agreement during such Year pursuant to the Approved Annual
Operating Plan for such Year, then the Fixed Costs and ROI for such
Year shall be increased by an amount equal to the number of hours
during which such Major Equipment was operated to produce coal
delivered to Buyers under this Agreement during such Year, multiplied
by the property taxes, return on investment and depreciation allocable
pursuant to generally accepted accounting principles consistently
applied to such Major Equipment for such Year, and divided by the total
number of hours such Major Equipment was operated during such Year. For
purposes of this subsection, if the Major Equipment is not Capital
Equipment, the return on investment with respect to such Major
Equipment shall be computed based on Seller’s then net book value for
such Major Equipment and utilizing the then current ROI rate for
pre-July I, 2000 investments as specified in subsection 12.5.1.
	 
	 	(e)	 	The credits and debits described in subsections
12.10(a),(b),(c) and (d) shall be applied prior to the application of
production taxes and royalties.
	 
	 	(f)	 	For purposes of this subsection 12.10, the
following terms shall have the following meanings: (i) “Capital
Equipment” means equipment and facilities the cost of which is taken
into account in the determination of the ROI charge; (ii) “Major
Equipment” means any item of equipment for which Seller maintains
hourly use records (including, but not limited to, all draglines,
shovels, coal drills, scrapers, dozers, haulers, shops and facilities,
but excluding pick-up trucks, tools and similar items); and (iii)
“Variable Charge” means the costs described in subsection 12.4.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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	 	(g)	 	Any usage of Major Equipment described in
subsections (c) and (d) and any sales of coal described in subsections
(a) and (b) shall be made by Seller only in compliance with an Approved
Annual Operating Plan and this Agreement.

     12.11. Impact of Force Majeure.

     If, because of Force Majeure Seller is unable to deliver, or Buyers are unable to take, all of
the coal budgeted pursuant to subsection 7.2, the depreciation pursuant to subsection 12.3 for coal
delivered during the Year in which said Force Majeure occurred shall be computed as though all the
coal ordered was delivered and the Force Majeure had not occurred. Any difference between the
amount actually paid for coal delivered during the Year affected by Force Majeure, and the amount
actually due by applying the provisions of this subsection 12.11, shall be promptly credited or
debited to Buyers.

     12.12. Cost Changes and Monthly Reports of Costs.

     Whenever a change occurs in any of the items of cost referred to in subsections 12.3, 12.4,
12.5 or 12.8, the amount of the change resulting therefrom in the cost to Seller of mining, selling
and delivering coal and land reclamation hereunder shall be determined and reported to Buyers.
Unless otherwise agreed by Seller and Buyers, Seller shall provide Buyers, within fifteen (15) days
after the end of each month, a report showing [**] for coal sold hereunder to Units 3 & 4 (and
comparisons against the Approved Annual Operating Plan and the accompanying Operating Budget and
Capital Budget) categorized as follows:

	 	(a)	 	[**] for [**] as used herein [**] of [**]
including [**] of [**] and [**] that [**] on the [**] of [**] and does
not include [**] or [**] that [**] on [**] ;
	 
	 	(b)	 	[**] of [**] and/or [**] for [**] ;
	 
	 	(c)	 	[**] on [**] of [**] into a [**] and [**] or
any [**] or [**] or [**] ;
	 
	 	(d)	 	[**] and [**] for [**] ;
	 
	 	(e)	 	[**] of [**] to or for the [**] of [**] for
[**] to or for the [**] of [**] to the extent that such [**] with or
are [**] with or [**] to [**] or [**] with the [**] or any [**] ;
	 
	 	(f)	 	[**] ;
	 
	 	(g)	 	[**] and [**] by [**] or by [**] to the extent
[**] ;
	 
	 	(h)	 	[**] of [**] to [**] and [**] ;
	 
	 	(i)	 	[**] and [**] including [**] other than [**] by
or [**] and [**] or [**] other than [**] to the extent [**] by [**] of
the [**] ;

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 37

 

	 	(j)	 	[**] to [**] based on [**] of [**] ;
	 
	 	(k)	 	[**] for [**] and [**] ;
	 
	 	(l)	 	[**] of [**] and [**] for [**] and [**] except
[**] ;
	 
	 	(m)	 	[**] for and [**] of [**] ; and
	 
	 	(n)	 	[**] of [**] by [**] pursuant to [**] .

     Seller shall also provide Buyers such substitute or additional information regarding the
actual costs of mining and delivering coal to the Point of Delivery under this Agreement as Seller
and Mine Operating Committee shall agree.

     12.13. Disputed Charges.

     Seller shall provide such information as Buyers may reasonably request to explain all cost
charges. Seller’s and Buyers’ respective books and records pertaining to any charges to the other,
or adjustments thereto, shall be subject to examination by the other pursuant to subsection 21.2.
Pending resolution of any dispute between the Parties regarding any costs charged under this
Agreement, each Buyer shall elect either to (i) pay Seller’s invoices under subsection 12.9 as if
the disputed amount had been agreed upon or (ii) withhold payment of any invoice to the extent
based upon the disputed portion of the proposed adjustment until resolution of the dispute. If any
Buyer pays a disputed amount and it is later determined that such amount was not due and payable,
Seller shall immediately refund to such Buyer the amount that was overpaid, together with interest
thereon from the date paid by such Buyer until the date refunded by Seller. If any Buyer withholds
any disputed amount under this subsection 12.13 and it is later determined that such amount was
properly due and payable, then such Buyer shall immediately pay such amount to Seller, together
with interest thereon from the date such amount was due (e.g., pursuant to subsection 12.9) until
the date paid. Interest under this subsection 12.13 shall be computed at the prime rate quoted from
time to time by Citicorp or such other financial institution as may be agreed upon by the Parties,
computed monthly and compounded semi-annually.

     12.14. Changes in Applicable Law or Circumstances.

     Any Party shall promptly notify each of the other Parties in writing of any change in any
applicable law, rule or regulation of which such Party becomes aware that has the potential to
adversely affect the present or future cost to Buyers of coal hereunder or the cost to Buyers of
generating electricity at Units 3 & 4 using coal delivered hereunder. A Party shall only be deemed
aware of any change or proposed change if the managerial personnel of such Party that are directly
involved in the administration of this Agreement have actual knowledge of such change or proposed
change. Any Party may, at its expense, take such action as it deems necessary or desirable to
protect its economic interests with respect to the implementation of such change. Without limiting
Buyer’s rights under this subsection 12.14, Seller shall cooperate in good faith with each Buyer in
Buyer’s efforts to oppose any change in an applicable law, rule or regulation that would limit,
diminish or otherwise adversely affect Buyers’ rights or economic interests under this Agreement.
Without limiting Seller’s rights under this subsection 12.14, Buyers shall cooperate in good faith
with Seller in Seller’s efforts to oppose any change in an

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 38

 

applicable law rule or regulation that would limit, diminish or otherwise adversely affect
Seller’s rights or economic interests under this Agreement.

13. PRICE ADJUSTMENT FOR Btu CONTENT

     13.1. Applicable Provisions.

     The price adjustment provisions set forth in Section 2 of Exhibit B hereto shall apply to all
coal delivered to the Point of Delivery on or before December 31, 1998. The price adjustment
provisions set forth in this Section 13 shall apply to all coal delivered to the Point of Delivery
on or after January 1, 1999 through the Term of this Agreement.

     13.2. Coal Exceeding [**] Btu/lb.

     If, based on sampling and analysis pursuant to this Agreement, the weighted average Btu
content of coal delivered to the Point of Delivery in a given Year exceeds [**] Btu/lb. there
shall be no price adjustment.

     13.3. Cents Per MMBtu Below Budgeted Cost.

     If, based on sampling and analysis pursuant to this Agreement, (a) the weighted average Btu
content of coal delivered to the Point of Delivery in a given Year is less than [**] Btu/lb. but
(b) the actual Variable Cost expressed as cents per MMBtu (the “Variable Cost per MMBtu”) of coal
delivered to the Point of Delivery in that Year is less than the Variable Cost per Btu set forth in
the Approved Operating Budget, there shall be no price adjustment. For purposes of this Section 13
only, the term “Variable Cost” shall include (a) Variable Charge for the Year, plus (b) actual fees
pursuant to subsections 12.5, 12.6 and 12.7 (profits derived through application of Exhibit B for
the period prior to July 1, 2000) plus (c) Royalties and Production Taxes associated with (a) and
(b) above.

     13.4. Cents Per MMBtu Above Budget Cost.

     If, based on sampling and analysis pursuant to this Agreement, (a) the weighted-average Btu
content of coal delivered to the Point of Delivery in a given Year is less than [**] Btu/lb. and
(b) the Variable Cost per MMBtu for coal delivered to the Point of Delivery in that Year exceeds
the Variable Cost per MMBtu set forth in the Approved Operating Budget, then Seller shall give
Buyers a credit equal to the product of (i) the Tonnage Increase and (ii) the Variable Cost of coal
as defined in subsection 13.3 multiplied by 1.13. “Tonnage Increase” means the additional tons of
coal that Buyers actually purchased as a result of the lower Btu content of the coal, as computed
in accordance with attached Exhibit D. Exhibit D also contains sample computations of this Btu
price adjustment.

     13.5. No Price Adjustment for Btu Deficiencies Arising in Certain Circumstances.

     Notwithstanding subsection 13.4, there shall be no price adjustment for Btu deficiency if (a)
there is a substantial deviation from an Approved Annual Operating Plan and the deviation is either
requested by the Mine Operating Committee or required by law, or (b) there is more than a ten
percent (10%) difference between tonnage contemplated by the Approved Annual Operating

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 39

 

Plan and the actual tonnage delivered to the Point of Delivery and the Parties have not agreed
upon a revised budgeted Variable Cost. In either case, Seller shall promptly propose a revision to
the Approved Annual Operating Plan under subsection 7.7 and the Mine Operating Committee shall use
best efforts to review, modify and approve or disapprove the proposed revision to the Approved
Annual Operating Plan as promptly as possible in accordance with subsection 7.7. The revised
Approved Annual Operating Plan shall thereafter govern for purposes of determining if a price
adjustment under subsection 13.4 is due for coal delivered during the Year in question. Disputes
concerning proposed revisions to an Approved Annual Operating Plan shall be resolved as provided in
subsections 7.7.1 and 8.1.

14. QUANTITY, THIRD PARTY SALES AND PURCHASES

     14.1. Requirements Obligation.

     Buyers shall purchase all of their coal requirements for Units 3 & 4 pursuant to the terms of
this Agreement, including subsection 14.3 below.

     14.2. Sales to Third Parties.

     Seller shall not sell or otherwise deliver to third parties during any Year, any coal produced
from Area C in an aggregate quantity in excess of [**] tons without the prior written consent of
the Mine Operating Committee, which consent shall not be unreasonably withheld. In no event shall
the sale of any coal from Area C to any third party or the use of any Capital Equipment outside of
Area C release or reduce Seller’s obligations to reserve for sale and delivery to Buyers the coal
dedicated under Section 2 and to deliver coal to Buyers in accordance with this Agreement. Unless
otherwise agreed by the Mine Operating Committee, all coal produced in Area C for sale or other
delivery to third parties shall be produced only in accordance with and subject to an Approved
Annual Operating Plan and from the same active mining areas, using the same mining methods, and
otherwise in conformity with Seller’s mining operations for the production of coal for delivery
under this Agreement. For all such third-party coal sales, Seller shall provide Buyers a credit
against amounts due Seller hereunder as provided in subsection 12.10.

     14.3. Coal from Outside Sources.

     The Parties recognize that the Original Coal Supply Agreement did not provide the Buyers with
the right to acquire Outside Coal for Units 3 & 4 or obligate Seller to permit or participate in
such acquisition. The Parties further recognize that this Agreement is the product of extensive
negotiations and mediation undertaken by all Parties for the purpose of resolving upcoming price
reopeners under the Original Coal Supply Agreement and avoiding further contentious and costly
disputes among the Parties. Therefore, the Parties acknowledge that as part of the negotiation of
the amounts of the ROI, Fixed Fee Per Ton and Incentive Fee Per Ton, the Parties agreed to permit
the acquisition of Outside Coal pursuant to this subsection 14.3 effective July 1, 2000.

     If an Approved Annual Operating Plan calls for the purchase of Outside Coal, Seller shall
purchase the Outside Coal as agent for the Buyers in accordance with Outside Coal

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 40

 

Commitments entered into pursuant to this subsection 14.3, except as provided in subsection
14.3.5.

          14.3.1. Seller to obtain offers.

     Seller shall from time to time obtain and present to Buyers offers from third parties or from
Seller to enter into Outside Coal Commitments for the supply of Outside Coal under this Agreement.
Seller shall present any such offer to the Mine Operating Committee as part of the proposed Annual
Operating Plan or as part of a proposed revision to an Approved Annual Operating Plan. Any Buyer
may obtain and present such an offer as part of the Annual Operating Plan or as part of a proposed
revision to an Approved Annual Operating Plan. This Agreement shall not be construed as obligating
Seller to offer to supply Outside Coal from reserves owned or controlled by Seller.

          14.3.2. Terms of offers.

     In obtaining an offer under this subsection 14.3, a Party shall use its good faith efforts to
ensure, and shall confirm in its presentation to the Mine Operating Committee, that (i) the terms
and conditions of the offer are fair, reasonable, and consistent with then-current market terms and
conditions available from other potential suppliers, (ii) to the extent such information is
available, that the terms and conditions of the offer are not less favorable than the terms and
conditions then being offered to others by the supplier or suppliers making the offer, and (iii) if
the Outside Coal is to be supplied from a source owned in whole or in part by Seller or by a person
that is directly or indirectly owned or controlled Seller, Seller has used its best efforts to
obtain competitive offers from at least three other suppliers for presentation to the Mine
Operating Committee.

          14.3.3. Seller to act as exclusive agent for Buyers to obtain Outside Coal.

     If Seller and the Mine Operating Committee approve a proposed Annual Operating Plan or a
proposed revision of an Approved Annual Operating Plan that calls for the purchase of Outside Coal,
Seller shall, except as provided in subsection 14.3.5, accept the offer or offers contemplated to
be accepted by such plan and enter into the approved Outside Coal Commitment in the name of and on
behalf of the Buyers. Buyers hereby appoint Seller as the Buyers’ exclusive agent to execute,
deliver, perform, enforce and administer Outside Coal Commitments entered into in the name and on
behalf of Buyers in accordance with this subsection 14.3, except as provided in subsection 14.3.5.
Seller shall use its best efforts to ensure compliance with all Outside Coal Commitments. All
Outside Coal Commitments shall be reviewed and approved by the affected Buyers) prior to execution
thereof by Seller. In addition, Seller shall obtain the affected Buyer(s)’ prior approval of any
material decision with respect to the performance, enforcement or administration of the Outside
Coal Commitments. Seller shall receive as a fee for providing the services described in this
subsection 14.3.3 from each Buyer who acquires Outside Coal during a Year an amount equal to the
product of (a) [**] of the [**] and [**] of [**] Fixed Fee Per Ton in effect [**] and [**] the
[**] of the Incentive Fee Per Ton for [**], and (b) the [**] of [**] of [**] to [**] during such
Year.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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          14.3.4. Price for Outside Coal.

     All costs of procuring and delivering Outside Coal, including capital improvements and any
other costs to facilitate such procurement and delivery, shall be borne by the electing Buyer(s).

          14.3.5. Potential third party [**] Outside Coal to Seller as agent.

     If following a good faith review of opportunities to obtain Outside Coal from third parties,
the Mine Operating Committee determines in good faith that third parties, for [**] or otherwise,
are generally [**] to [**] to [**] Outside Coal to Seller acting as agent [**] or on [**] and
[**] , then Buyers [**] to [**] for [**] of [**] . It is the intention of the Parties, however,
that to the extent practical [**] to [**] the [**] related to [**] in [**] . Moreover, it is the
intention of the Parties that [**] by [**] shall not result in [**] from the [**] to [**] , as
opposed to [**] . Finally, Buyers agree that the [**] to [**] to [**] for [**] in any way [**] of
[**] and [**] to [**] shall be [**] for all purposes as [**] by [**] to [**] .

15. FINAL RECLAMATION COSTS

     For purposes of this Agreement, “Reclamation” means all activities that must be performed by
Seller to comply with now existing or hereafter adopted state and federal laws, rules and
regulations that deal with land reclamation and environmental matters and apply to surface mining
coal operations. The term “Current Reclamation” as used in this Agreement means the reclamation
that occurs during the progress of mining on a pass-by-pass basis within an Area C mining pit but
only to the extent undertaken by Seller pursuant to an Approved Annual Operating Plan or this
Agreement prior to closure of Area C or any mining pit within Area C. Seller shall be reimbursed
for the costs of Current Reclamation pursuant to subsection 12.4 of this Agreement. With respect to
final reclamation, the Parties agree that different terms and conditions apply to the obligations
between Seller and Puget on the one hand, and between Seller and all Buyers other than Puget on the
other hand (for purposes of this Section 15 the Buyers other than Puget shall be referred to as the
“Non-Puget Buyers”). The terms and conditions relative to Puget’s obligations in relation to
Seller’s obligations for final reclamation are set out in subsection 15.3. The terms and conditions
with respect to final reclamation relative to the Non-Puget Buyers are set out in subsections 15.2
and 15.4(b) Because of the different terms and conditions applicable to Puget as opposed to the
Non-Puget Buyers with respect to final reclamation, a single definition of the term “final
reclamation” is not used for purposes of this Agreement, but rather two different definitions are
used. “Subsection 15.2 Final Reclamation” means that reclamation that occurs at or after closure of
Area C or closure of a mining pit within Area C, including but not necessarily limited to, final
pit highwall reduction and reclamation, final pit endwall reduction and reclamation, final pit and
ramp closure and reclamation, facilities decommissioning and site removal, related revegetation,
soil removal and/or application, environmental compliance and monitoring activities and other
postmine management, and associated A&G and other costs related to such activities. “Subsection
15.3 Final Reclamation” has the meaning ascribed to it in subsection 15.3(b).

     15.1. Reclamation Account

     As of the Effective Date of this Agreement, the Buyers have paid funds earmarked for final
reclamation that are maintained in a reclamation account (the “Reclamation Account”)

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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created pursuant to the May 6, 1996 arbitration decision rendered by Judge Sheran (the
“Arbitration Decision”). This Section 15: (i) defines the obligations of the Parties concerning
final reclamation, (ii) provides methods for securing the obligations of the Parties concerning
final reclamation and (iii) provides for the closing and termination of the Reclamation Account.

     15.2. Obligations of Seller and Non-Puget Buyers to Each Other For Final Reclamation

     A. Each Non-Puget Buyer hereby irrevocably releases to Seller for deposit into the “Seller’s
Account” described in subsection 15.4 all funds held in the Reclamation Account for the benefit of
such Non-Puget Buyer.

     B. Seller irrevocably releases each Non-Puget Buyer from any and all obligations to pay the
costs of final reclamation, including without limitation, Subsection 15.2 Final Reclamation, as the
result of coal purchased from Seller under the Original Coal Supply Agreement or this Agreement,
including coal to be mined and delivered in the future. Such release shall be effective regardless
of the ultimate costs of final reclamation, including, without limitation, Subsection 15.2 Final
Reclamation, or changes in law (or changes in interpretation of existing law) that affect such
costs or changes in law that affect which parties may be responsible for such costs.
Notwithstanding any provision of this Agreement to the contrary, all Non-Puget Buyers shall have no
obligation for Subsection 15.2 Final Reclamation costs or to pay any costs incurred by Seller that
are properly classifiable as costs of Subsection 15.2 Final Reclamation (including, without
limitation, A&G and costs associated with compliance with new laws enacted after the Effective Date
or changed interpretations of existing laws, if such A&G and other costs are attributable to
Subsection 15.2 Final Reclamation).

     C. Seller shall maintain all reclamation bonds now in place until modified bonds or additional
bonds are required, and then shall maintain all such modified or additional bonds as may be
required by the Montana Department of Environmental Quality or any other authorized regulatory
agency with responsibility for mine reclamation. Montana shall maintain its indemnity in favor of
the surety of Seller’s obligations under the present reclamation bonds and shall indemnify in
substantially the same form all of Seller’s obligations under the terms of all modified or
additional bonds required as described above. Montana may not assign the obligations created by
this subsection 15.2.C. without the written consent of each Non-Puget Buyer which consent shall not
be unreasonably withheld.

     D. In addition to the security required by subsection 15.2.C. above, Seller and Entech, Inc.
(“Entech”) shall indemnify, defend and hold harmless each Non-Puget Buyer from any and all
expenses, claims, attorneys’ fees and other costs resulting from any claim by any person or entity
that any Non-Puget Buyer is responsible for any expenses of Subsection 15.2 Final Reclamation.
Montana shall provide to each Non-Puget Buyer, either (i) additional financial assurance in the
form of a letter of credit, performance bond, or other instrument in form and amount reasonably
acceptable to such Non-Puget Buyer and reasonably necessary to assure coverage of Subsection 15.2
Final Reclamation costs, or (ii) at Montana’s option, an indemnity from Montana, in form and
substance equivalent to the indemnity provided by Entech and Seller in this subsection 15.2 and
Exhibit E, if the Consolidated Net Worth of Entech, at any year end, is less than $ [**] million
(as used herein “Consolidated Net Worth” shall be

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 43

 

determined in accordance with generally accepted accounting principles consistently applied).
Beginning on July 1, 2000 and every five years thereafter, this measure of Consolidated Net Worth
shall be adjusted for inflation or deflation, and to compute the new value the Seller and the
Non-Puget Buyers shall use the [**] , first published for the three-month period ending July 1,
[**] as the base. If the [**] ceases to be published by the [**] or any other federal agency
or is rebased or otherwise modified, such index shall be replaced by a substantially equivalent
index that, after necessary adjustment, if any, provides the most reasonable substitute for such
index and which is mutually agreeable to the Seller and to all of the Non-Puget Buyers. If an
agreement cannot be reached within ninety (90) days of discontinuance of such index, then the
matter shall be submitted to the Executive Committee (constituted for these purposes without
Puget’s representative) for dispute resolution, and if the Executive Committee (as so constituted)
does not resolve the dispute within thirty (30) days thereafter, the matter shall be submitted to
binding “last best offer” arbitration pursuant to subsection 8.3. The values of all amounts shall
be established by audited financial statements, if available, or by unaudited financial statements
prepared on a basis consistent with the most recent audited financial statements, if audited
financial statements are not available. This subsection 15.2.D. is intended to establish a right
only in favor of the Non-Puget Buyers, (including their permitted successors and assigns) and may
not be enforced or exercised by any other person or entity. The obligations of Seller, Entech and
Montana created by this subsection 15.2.D. shall not be assigned without the written consent of
each Non-Puget Buyer which consent shall not be unreasonably withheld. By execution of Exhibit E to
this Agreement, Entech agrees jointly and severally with Seller to indemnify the Non-Puget Buyers
as described in this subsection 15.2.D.

     15.3. Obligations of Seller and Puget to Each Other for Final Reclamation

	 	(a)	 	In connection with the Reclamation Account,
Seller and Puget agree that Seller shall promptly release to Puget
certain funds contained in the Reclamation Account as set forth in this
subsection 15.3(a). The Reclamation Account payment to Puget shall be
in an amount equal to [**] % of the current account balance in the
Reclamation Account attributable to coal payments made by Puget under
the Original Coal Supply Agreement (the “Puget Reclamation Account
Balance”). Seller would retain the remaining [**] % of the Puget
Reclamation Account Balance, and Puget acknowledges and agrees that
Seller is not required to keep such [**] % amount in the Reclamation
Account, but may release it to Seller or Montana.
	 
	 	(b)	 	As used in this subsection 15.3(b), the “Puget
Coal Fraction” means a fraction, the numerator of which is the product
of [**] % multiplied by the Total Area C Tons Mined that 11 purchased
by Puget and its successor(s) in interest under the Original Coal
Supply Agreement and this Agreement, and the denominator of which is
the Total Area C Tons Mined. “Total Area C Tons Mined” means the total
tons of coal mined from Area C up to the cessation of mining in such
Area C and before the completion of Subsection 15.3 Final Reclamation.
“Subsection 15.3 Final

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	 	 	 	Reclamation” means final reclamation activities required by
applicable regulatory agencies until such time as final bond release
of all bonds is approved by such regulatory agencies, such activities
including, without limitation, facilities site removal and vegetation
and monitoring activities. The total amount Puget, or its
successor(s) in interest, shall be obligated to pay under the
Original Coal Supply Agreement and this Agreement for Subsection 15.3
Final Reclamation with respect to Area C shall be an amount equal to
the product of the Puget Coal Fraction multiplied by the Subsection
15.3 Final Reclamation costs attributable to Total Area C Tons Mined
(such product is hereinafter referred to in this Section 15.3(b) as
the “Puget Obligation”). With respect to the Puget Obligation, Puget
or its successor(s) in interest shall have the option of either (i)
paying the Puget Coal Fraction share of such Subsection 15.3 Final
Reclamation costs as such costs are accrued or, alternatively, (ii)
paying the Puget Coal Fraction share of such Subsection 15.3 Final
Reclamation costs as such costs are incurred. Should Puget or its
successor(s) in interest elect the option to pay the Puget Coal
Fraction share of such Subsection 15.3 Final Reclamation costs as
such costs are incurred, then Puget or its successor(s) in interest
shall be required to provide and maintain security to Seller for the
Puget Obligation in the form of a bond, letter of credit or corporate
guaranty from an investment-grade-rated company (or other security
satisfactory to Seller). Puget or its successor(s) in interest shall
have the right to audit such Subsection 15.3 Final Reclamation costs
and the Puget Coal Fraction. Except for the Puget Obligation, Seller
shall be obligated for and shall pay the total Subsection 15.3 Final
Reclamation costs attributable to the share Puget and its
successor(s) in interest of Total Area C Tons Mined under the
Original Coal Supply Agreement and this Agreement. Puget and its
successor(s) in interest are each hereby released by Montana and
Seller from any further obligation or liability with respect to such
share. Seller shall continue to maintain a bond as required by the
state of Montana and applicable regulatory agencies for Seller’s
statutory Subsection 15.3 Final Reclamation cost payment obligation,
and Montana shall support such bond as reasonably necessary.
	 
	 	(c)	 	In connection with its receipt of the
Reclamation Account distribution contemplated hereunder, Montana,
Seller and Puget irrevocably agree that the requirements to fund and
maintain Puget’s interest in the Reclamation Account as stated in the
Arbitration Opinion are superseded and replaced by the terms hereof and
that with respect to Puget and any successor(s) in interest to Puget’s
interests in the Original Coal Supply Agreement, Seller will have no
further obligation to maintain and fund the

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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	 	 	 	Reclamation Account as it pertains to Puget or its successor(s) in
interest.
	 
	 	(d)	 	Puget, Seller and Montana shall cooperate in
evaluating whether credits or refunds of taxes and royalties on the
distribution to Puget pursuant to subsection 15.3(a) should be pursued.
If Puget determines that it desires to pursue such credits or refunds,
then Seller and Puget shall work together to pursue such credits or
refunds, unless Montana or Seller determine that such pursuit could
reasonably be expected to adversely affect their income statements
under generally accepted accounting principles or other interests of
Montana or Seller. If Puget and Montana or Seller are unable to agree
to pursue credits or refunds, then the CEOs of Puget and Montana shall
meet within twenty (20) business days to resolve the dispute. If the
dispute is not resolved at this meeting, then either party may pursue
its available legal remedies, unless the Parties mutually agree to an
alternative dispute resolution procedure. Puget will assume the risk
and hold Seller harmless from any and all expenses related to this
effort. Puget acknowledges that Seller and Montana offer no assurances
that efforts to obtain any credits or refunds will be successful. If
credits or refunds are obtained, then Seller shall pay or credit to
Puget or its successor(s) in interest its share of such refunds or
credits.

     15.4. Closing of the Reclamation Account and Creation and Maintenance of Seller’s Account.

	 	(a)	 	Upon execution of this Agreement, Seller shall
be entitled to close and terminate the Reclamation Account, Seller
shall have no further obligation relative to such account, and the
obligations of the Parties concerning final reclamation shall be
addressed as provided in this Section 15.
	 
	 	(b)	 	The terms and conditions in this subsection
15.4(b) apply only to Seller and the Non-Puget Buyers. All funds
released to Seller by any Buyer pursuant to subsections 15.2.A. or
15.3(a) shall be held in a “Seller’s Account” to be established by
Seller at a financial institution chosen by Seller. Funds from Seller’s
Account shall be used to pay for Seller’s share of Subsection 15.2
Final Reclamation. The funds, in the Seller’s Account shall be invested
and managed at Seller’s sole discretion in order to maintain sufficient
funds in Seller’s Account to satisfy its obligations regarding
Subsection 15.2 Final Reclamation. Seller may withdraw funds from
Seller’s Account for its general use whenever the funds in the Seller’s
Account exceed the sum estimated to be required to meet its remaining
obligations regarding Subsection 15.2 Final Reclamation as measured
against the life of mine plan contained in

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 46

 

	 	 	 	the Approved Annual Operating Plan (“Subsection 15.2 Final
Reclamation Estimate”). Seller must deposit funds into Seller’s
Account whenever the funds in the Seller’s Account are inadequate to
meet its obligations regarding Subsection 15.2 Final Reclamation as
measured against the Subsection 15.2 Final Reclamation Estimate.
Seller shall be solely responsible for income and any other taxes
incurred with respect to funds maintained or earned in Seller’s
Account. Upon the request of any Non-Puget Buyer, Seller shall
provide an accounting reflecting the total funds held in the Seller’s
Account.

16. FORCE MAJEURE AND PLANT OUTAGES.

     16.1. Force Majeure.

     If, because of Force Majeure, any Party shall be unable to carry out any of its obligations
under this Agreement, then the obligations of such Party shall be suspended to the extent made
necessary by such Force Majeure. The Party affected by Force Majeure shall give notice to the other
parties as promptly as practicable of the nature and probable duration of such Force Majeure. The
term “Force Majeure” shall mean acts of God, legislation or lawful regulations of any governmental
body, court orders, acts of the public enemy, riots, strikes, labor disputes, labor or material
shortages, fires, explosions, floods, breakdowns of or damage to plants, mines, transmission lines,
equipment or facilities, interruptions in transportation, embargoes, or other causes of similar
nature beyond the affected Party’s control which wholly or partially prevent the delivery of the
coal by Seller, the receiving or consuming of the coal by Buyers, or the operation of Units 3 & 4.
Buyers and Seller shall use all reasonable means of preventing the occurrence of any of the
foregoing. Nothing contained herein shall be construed so as to require a Party to settle any
strike or labor dispute in which it may be involved. Any Party rendered unable to fulfill any
obligation by reason of Force Majeure shall exercise due diligence to remove such inability with
all reasonable dispatch.

     16.2. Plant Inoperability.

     If either Unit 3 or Unit 4 is rendered inoperable as the result of physical damage,
legislation or lawful regulation of governmental body, court order or other causes of a similar
nature that prevent further operation of the generating plant, and if the Buyers have notified
Seller in writing that the unit will not be restored, rebuilt or otherwise made operable, then
Seller’s obligation to deliver and Buyers’ obligation to take and pay for coal with respect to such
Unit, including Fixed Costs, shall terminate as of the date provided in the notice;
provided, however, that the Buyers shall be liable to Seller for any loss (other
than royalties or loss of profits) sustained by Seller as a result of such termination of
deliveries, and Seller shall use all reasonable efforts to minimize any such loss. If one Unit is
rendered inoperable, and the other Unit remains operable, Buyers’ and Seller’s obligations referred
to above shall be reduced by half.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     16.3. Depreciation Suspension.

     Buyers’ obligation to pay depreciation shall be suspended or reduced after three months of
continuous interruption or curtailment of deliveries because of a Force Majeure affecting Buyers or
Seller. Depreciation paid during any Years when deliveries are interrupted or curtailed because of
a Force Majeure shall be subject to adjustment pursuant to subsection 12.11.

17. WAIVERS AND REMEDIES

     17.1. Non-waiver.

     The failure of any Parry to insist in any one or more instances upon strict performance of any
of the provisions of this Agreement or take advantage of its right hereunder shall not be construed
as a waiver of any such provisions or their relinquishment of any such right, but the same shall
continue and remain in full force and effect.

     17.2. Right to Cure.

     No default of any Party to the Agreement in the performance of any of its covenants or
obligations hereunder which, except for this provision, would be the legal basis for rescission or
termination of this Agreement by any other Party hereto, shall give or result in such a right
unless and until the Party committing such default shall fail to correct the default within sixty
(60) days or within a reasonable time if not correctable within sixty (60) days after written
notice of claim of such default and a statement setting forth the nature thereof are given to such
defaulting Party by the Party claiming such default.

     17.3. Seller’s Default.

     In the event of the occurrence of one or more of the following events which materially and
adversely affect or will affect the ability of Seller to perform hereunder as agreed, Buyers shall
have the rights set forth in subsection 17.4, which rights shall be in addition to all other rights
or remedies provided Buyers at law or in equity in the event of a default by Seller:

	 	(a)	 	Seller defaults in the performance of any of
its obligations hereunder, which default adversely affects, or will
adversely affect, the delivery by Seller of coal to Buyers in the
required quantity and quality;
	 
	 	(b)	 	Seller becomes insolvent, or becomes the
subject of a petition in bankruptcy, either voluntarily or
involuntarily, or any other proceeding in the federal bankruptcy laws;
or is named in, or Seller’s Mine, buildings, equipment of other
facilities are subjected to, a suit for an appointment of receiver;
	 
	 	(c)	 	Seller becomes delinquent in the performance of
any financial obligation; or
	 
	 	(d)	 	Seller commits an anticipatory breach of any of
its obligations hereunder.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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     Seller agrees to promptly notify Buyers of any default, financial delinquency or claimed
delinquency, insolvency, or anticipatory breach as described above. Failure of Seller to agree upon
an Annual Operating Plan or other proposed decision of the Mine Operating Committee is not itself
an act of default.

     17.4. Buyers’ Remedies.

     In the event of any occurrence of any of the items set forth in subsection 17.3 above, Buyers
jointly and severally shall have all of the following rights, in addition to those provided at law
or in equity:

	 	(a)	 	To pay any financial obligations of Seller and
to recover the amounts of such payments from Seller or offset them
against any amounts due from any Buyer to Seller;
	 
	 	(b)	 	To require that Seller furnish evidence, in a
form satisfactory to Buyers, of financial capability to perform its
obligations under this Agreement;
	 
	 	(c)	 	To [**] the [**] ; to [**] of [**] and [**]
for the [**] and [**] hereunder; to [**] and [**] , but [**] the
[**] and [**] , which [**] shall be [**] ; and to [**] and [**]
        , including [**] , relating to the [**] , with Seller to be [**] and
[**] , including [**] and [**] and [**] and [**] and [**] ; and
	 
	 	(d)	 	To require Seller to invite bids from qualified
operators to operate in Area C and perform the obligations of Seller
under this Agreement for the remainder of its Term. Invitations to bid
shall be sent to all operators nominated by Seller and Buyers, which
operators must have had experience in strip mining or comparable
experience. Seller shall [**] and [**] the [**] and [**] of [**]
of [**] the [**] of [**] .

18. SUCCESSORS AND ASSIGNS

     This Agreement shall inure to the benefit of and be binding upon the Parties hereto and their
respective successors and assigns. This Agreement may be assigned and transferred by the Buyers
only as set forth in subsection 18.1 herein and may be assigned and transferred by Seller only as
set forth in subsection 18.2 herein, and not otherwise.

PAGE 49

 

     18.1. Assignment of Buyer’s Interest.

     The undivided interest of Buyers, or any of them, in this Agreement or any part thereof may be
transferred or assigned to a third party only in conjunction with an assignment or transfer to said
third party by Buyers, or any of them, of a portion or all of its owner’s interest in the Project,
pursuant to Section 24 of the Units 3 & 4 Ownership and Operation Agreement; provided,
however, that Montana’s obligations under subsections 15.2.C. and 15.2.D. may not be
assigned except as provided under those subsections.

     18.2. Assignment of Seller’s Interest.

     Seller’s interest in this Agreement may be transferred or assigned to a third party only in
conjunction with the assignment or transfer to said third party of Seller’s entire ownership and
operating interests, including mineral leases, in and to coal located in Area C that is dedicated
to the performance of this Agreement pursuant to Section 2. Such an assignment or transfer may be
made by Seller only after Seller has first offered to transfer its interest in this Agreement and
in its ownership and operating interests in and to the coal located in Area C to Buyers for the
amount of and on terms not less advantageous than those of a bona fide offer from a buyer able and
willing to purchase Seller’s interest. Seller shall advise Buyers in writing of the name of the
proposed buyer, the proposed purchase price, the terms of sale and of such other information as may
be necessary in order for Buyers to properly evaluate the offer: Buyers shall have three (3) months
after the written notice from Seller to elect to exercise the right to purchase. If Buyers elect
not to purchase the leases and other ownership interests in or to the coal located in Area C, then
Seller may assign or transfer its interest in this Agreement and the leases and other ownership
interests in or to the coal in Area C to the person named in the notice to Buyers (“Third Party
Transferee”), which assignment or transfer shall be made subject to the following conditions:

	 	(a)	 	The assignment or transfer to the Third Party
Transferee must be completed within one (1) year from the date of the
notice to Buyers;
	 
	 	(b)	 	As a condition of the assignment or transfer,
the Third Party Transferee must agree to be bound by each and every
term and condition of this Agreement as if such Third Party Transferee
were an original party to this Agreement, including the restriction on
transfers and assignments;
	 
	 	(c)	 	The transfer or assignment to the Third Party
Transferee shall not directly or indirectly result in an increase in
any of the costs set forth in Section 12. Without limiting the
generality of the foregoing, the following shall apply: if the Third
Party Transferee’s costs for any items are higher than Seller’s costs
for the same items, then the Third Party Transferee shall absorb the
difference in costs; the Third Party Transferee shall maintain the same
depreciation basis and rates with respect to any transferred equipment
as that maintained by Seller pursuant to subsection

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 50

 

	 	 	 	12.3.1; and any increase in ad valorem or other taxes resulting or
based upon the transfer shall be absorbed by the Third Party
Transferee; and
	 
	 	(d)	 	Prior to the transfer, the Third Party
Transferee shall furnish evidence satisfactory to each of the Buyers of
its financial capability to perform under this Agreement and shall
furnish, if requested by any of the Buyers, a bond in form satisfactory
to Buyers guaranteeing to Buyers that the Third Party Transferee will
perform each of the terms and conditions of this Agreement and will
meet all of its financial obligations as required, including promptly
paying any royalties due under coal leases or other agreements.

19. LAW GOVERNING CONSTRUCTION OF AGREEMENT

     The Parties to this Agreement are domiciled in three different states. In order to create
greater certainty with respect to their legal rights and obligations under this Agreement, the
Parties desire to adopt as the substantive law of this Agreement the law of a state which has
highly developed commercial law and precedent and which is not the domicile of any of the Parties.
The Parties therefore agree that this Agreement shall be subject to and governed by the substantive
laws of the State of New York as though this Agreement were performed in full in the State of New
York, but without giving effect to New York principles of conflicts of laws.

20. NOTICES AND REPORTS

     All notices or reports provided for under this Agreement shall be in writing and shall be sent
by United States mail, postage prepaid, and properly addressed:

	 	(a)	 	If to Buyers:

Puget Sound Energy, Inc.

One Bellevue Center Bldg.

Bellevue, Washington 98004-5515

Attention: Vice President, Energy Supply

The Washington Water Power Company

1411 East Mission

P.O. Box 3727

Spokane, Washington 99220

Attention: Vice President, Energy Marketing & Trading

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 51

 

Portland General Electric Company

121 SW Salmon St.

Portland, Oregon 97205

Attention: Vice President, Power Supply

PacifiCorp

One Utah Center, Suite 2000

201 South Main Street

Salt Lake City, Utah 84140

Attention: Director, Fuel Resources

The Montana Power Company

40 East Broadway

Butte, Montana 59701

Attention: Executive Vice President, Supply Division

	 	(b)	 	If to Seller:

Western Energy Company

16 East Granite

Butte, Montana 59701

Attention: Vice President, Coal Division

21. RECORDS TO BE KEPT

     21.1. Maintenance and Provision of Information.

     Seller shall keep accurate and satisfactory records and books of account of the entire Rosebud
Mine and all costs related thereto (and all other information and data relative to the
determination of Seller’s performance against budgets), including, but not limited to, all costs,
payments, price revisions, adjustments, credits, debits and all other data required for the
purposes of this Agreement. Whenever the Price is revised in accordance with the provisions of
Section 12 and at any other time upon fifteen (15) days notice from Buyers, or any of them, Seller
shall furnish or cause to be furnished to such Buyers a detailed statement showing Seller’s Price
as revised and the basis for the revisions to be made. If any such statement discloses that any
error has occurred and that, as a result thereof, an overpayment or an underpayment has been made,
the amount thereof shall promptly be paid or credited to the Party to whom it is owed by the other
Party.

     21.2. Audit Rights.

     Seller and Buyers shall have the right at all reasonable times to examine the records kept by
the other concerning this Agreement, including weights and analysis of the coal delivered
hereunder.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

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22. NO SALES AGENT

     Seller represents that it is the owner or lessee of the Mine and facilities for producing and
delivering of said coal and is not represented by a sales agent in respect to this Agreement.

23. OPERATOR

     The Parties hereto acknowledge that Buyers are parties to the Units 3 & 4 Ownership and
Operation Agreement. Seller agrees to recognize whomever Buyers designate from time to time as the
Operator of Units 3 & 4 as the agent of Buyers thereunder for purposes of scheduling deliveries and
the giving of notices herein mentioned respecting all coal delivered under this Agreement until
such time as Buyers in writing designate a new or different agent. Nothing herein shall prevent any
Buyer from acting on its own behalf respecting coal deliveries hereunder providing it first
notifies, in writing, the other Parties of its intention to do so.

24. PERPETUITIES

     If the duration of any term or condition of this Agreement shall be subject to the rule
against perpetuities or a similar or related rule, then the effectiveness of such term or condition
shall not extend beyond (a) the maximum period of time permitted under such rule, or (b) the
specific applicable period of time expressed in this Agreement, whichever is shorter. For purposes
of applying the rule against perpetuities or a similar or related rule the measuring lives in being
shall be those of the officers of Buyers, respectively, listed by name on Page 107, Schedule of
officers, of the annual report, FERC Form 1, filed with the Federal Energy Regulatory Commission
for the year ended on December 31, 1997, together with all those officers’ children that are living
on the date of execution of this Agreement. As used in this subsection the word “children” shall
have its primary and generally accepted meaning of descendants of the first degree.

25. COMPLIANCE

     Seller shall comply with all applicable laws and regulations in its performance of this
Agreement.

26. [**]

     [**] If after the date of execution of this Agreement Seller [**] a [**] or [**] with [**]
or [**] with respect to [**] , then Seller shall [**] , in either case [**] . This provision
shall not require Seller to [**] .

27. SEVERAL LIABILITY

     The Parties agree that the liability of Buyers hereunder is several, not joint, and that if
there is a breach or default hereunder by Buyers or any one of them, that no other Party hereto
shall have any obligation to perform for the breaching or defaulting Buyers) and that Seller shall
have no claim against or power to bind any other Buyer or any other Party (other than a successor
to a breaching or defaulting Buyer) for the breaching or defaulting Buyer’s obligations hereunder.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 53

 

28. CONFIDENTIALITY

In order to achieve fully their objectives, the Parties anticipate it will be necessary for
them to disclose to one or more Parties certain information which is confidential, proprietary or
not generally available to the public (“Confidential Information”); therefore, the Parties agree to
the terms of this Section 28 governing the disclosure and use of Confidential Information.

     28.1. Labeling Information “Confidential”.

     All written or other tangible information which any Party wishes to be covered by this Section
28 shall be marked “Confidential” at the time of disclosure. Any information transmitted orally or
by demonstration which any Party wishes to be covered by this Section 28 shall be identified as
Confidential Information at the time of disclosure and confirmed in writing as being Confidential
Information within ten (10) days of disclosure.

     28.2. Duty Not to Disclose.

     The recipient of Confidential Information shall protect such information from inadvertent
disclosure and keep it strictly confidential. The recipient shall not disclose Confidential
Information to any other person, without the written consent of the owner of the Confidential
Information, which may be withheld in the owner’s sole discretion, except as may reasonably be
required by law or with respect to regulators, taxing authorities and/or third party royalty
holders. Disclosure of any information by a director, officer, employee, consultant, agent,
representative, lender, legal counsel, advisor and the like of any Party or of that Party’s
affiliates or subsidiaries of a Party shall be deemed a disclosure by that Party. The recipient
shall use the Confidential Information solely for the limited purposes of performing its
responsibilities under this Agreement.

     28.3. Notice Prior to Compulsory Disclosure.

     In the event the recipient of Confidential Information is requested or required, by subpoena,
oral deposition, interrogatories, request for production of documents, administrative order or
similar demand or process, to disclose any Confidential Information, the recipient shall provide
the owner of such Confidential Information with prompt notice of such requests) so that the owner
may seek, at its expense, an appropriate protective order.

29. EXECUTION OF AGREEMENT

     Seller and each of the Buyers respectively warrant and represent that the execution and
delivery of this Agreement have been duly authorized and that all requisite actions to be taken to
make this Agreement and all terms hereof valid and binding on it have been taken.

30. COUNTERPARTS

     This Agreement may be executed in any number of counterparts, all of which taken together
shall constitute one agreement, and any Party may execute this Agreement by signing any such
counterpart.

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 54

 

     IN WITNESS WHEREOF, the Parties hereto have caused this Amended and Restated Coal Supply
Agreement to be duly executed as of the day and year first above written.

	 	 	 	 	 	 	 	 	 	 	 
	WESTERN ENERGY COMPANY:	 	 	 	PUGET SOUND ENERGY, INC.:	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ Paul Gatzmeier
 

	 	 	 	By:
	 	/s/ W.A. Gaines
 

	 	 
	Its:

	 	President
	 	 	 	Its:	 	 	 	 
	 

	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	MONTANA POWER COMPANY:	 	 	 	PACIFICORP:	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ B.F. Cramer
	 	 	 	By:
	 	/s/ Dan R. Bank	 	 
	 

	 	 
	 	 	 	 	 	 	 	 
	Its:

	 	Executive Vice President and
	 	 	 	Its:
	 	Vice President	 	 
	 

	 	Chief Operating Officer of
Energy	 	 	 	 	 	 	 	 
	 

	 	Supply Division	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	THE WASHINGTON WATER POWER COMPANY:	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ signature not legible
 

	 	 	 	 	 	 	 	 
	Its:

	 	Senior Vice President	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PORTLAND GENERAL ELECTRIC COMPANY:	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ Walter Pollack
 

	 	 	 	 	 	 	 	 
	Its:

	 	Senior Vice President, Power Supply	 	 	 	 	 	 	 	 

AMENDED AND RESTATED COAL SUPPLY AGREEMENT

PAGE 55

 

EXHIBIT A

OWNERSHIP OF CAPACITY

	 	 	 	 	 
	Entity	 	Capacity Share
	Montana Power Company
	 	 	30	%
	 
	 	 	 	 
	Puget Sound Energy, Inc.
	 	 	25	%
	 
	 	 	 	 
	Portland General Electric Company
	 	 	20	%
	 
	 	 	 	 
	The Washington Water Power Company
	 	 	15	%
	 
	 	 	 	 
	PacifiCorp
	 	 	10	%

 

 

EXHIBIT B

PRICE PROVISIONS APPLICABLE PRIOR TO JULY 1, 2000

     The provisions of this Exhibit B shall be applicable to coal delivered under this Agreement
prior to July l, 2000; provided, however, that the provisions of Section 2 shall be
applicable only to coal delivered prior to January 1, 1999. The Parties intend that the provisions
of this Exhibit B be interpreted and applied consistent with the Parties’ practices just prior to
the execution of this Agreement with two exceptions: (1) all costs of labor included in the Price
charged by Seller to Buyers shall be equal to actual costs and on no other basis and (2) all costs
of [**] included in the Price charged by Seller to Buyers shall be equal to [**] paid by Seller
and on no other basis. Consistent with this intention, attached as Exhibit B1 are sample
calculations which have been modified to reflect the foregoing two modifications. Attached as
Exhibit B2 hereto is the [**] price adjustment calculation performed by Seller which, except to
the extent of the two foregoing modifications, reflects the Parties’ practices, with respect to
price adjustments to be made pursuant to Section 3 below; provided, however, that
modifications made as a result of resolution of items identified by Buyers as audit items may
result in further modification to the Parties’ practices.

1. BASE PRICE AND PAYMENT

     1.1. Price Prior to July 1, 2000.

     The Price for coal delivered by Seller hereunder from Area C from January 1, 1998 through June
30, 2000 shall be on a cost-plus basis where Buyers pay their proportionate share of actual labor
and other costs (specifically including [**] ) following a least-cost mine plan, which in the case
of an Approved Annual Operating Plan shall be the Mine Plan reflected in the Approved Annual
Operating Plan. The Price to be paid by Buyers for coal delivered by Seller hereunder shall be the
price per ton computed from the sum of (a) and (b), minus (c) in this subsection 1.1. To the extent
application of (a) and (b) would result in charges in excess of the actual costs of producing and
delivering coal to Buyers under this Agreement, then Seller shall charge, and Buyers shall pay,
such actual costs and not any other amount.

	 	(a)	 	Fixed Charge. An annual charge of ($
[**] ) to be paid in monthly installments at the rate of one-twelfth
(1/12) of said amount; and
	 
	 	(b)	 	Commodity Charge. $ [**] per ton
reduced by that portion (if any) of the amounts paid by Buyers to
Seller under that certain Coal Transportation Agreement entered into as
of July 10, 1981 between Buyers and Seller, which portion is properly
allocable to transportation of coal to the eastern boundary of Area C,
approximately 4.23 miles (i.e., approximately 4.46 conveyor
belt miles) from Units 3 & 4.
	 
	 	(c)	 	1988 Amendment Credit. $ [**] per ton.

1

 

     1.2. Credits.

	 	(a)	 	If in any Year Seller sells or otherwise
delivers to third parties any coal produced in Area C using any Capital
Equipment, Buyers shall promptly receive a credit towards the payment
of the Fixed Charge for such Year equal to the number of tons of coal
so sold to third parties, multiplied by such Fixed Charge, and divided
by 6,000,000 tons.
	 
	 	(b)	 	If in any Year Seller sells or otherwise
delivers to third parties any coal produced in Area C, Buyers shall
promptly receive a credit for such Year equal to the number of tons of
coal so sold to third parties, multiplied by the Operating Costs for
such year, and divided by the total number of tons of coal produced in
Area C during such Year.
	 
	 	(c)	 	If in any Year Seller uses any Major Equipment
that is Capital Equipment outside of Area C, Buyers shall promptly
receive a credit towards the payment of the Fixed Charge for such Year
equal to the number of hours during which such Major Equipment was
operated outside of Area C during such Year, multiplied by that portion
of the Fixed Charge for such Year which is allocable to property taxes
and depreciation and which is allocable to such Major Equipment, and
divided by the total number of hours such Major Equipment was operated
during such Year. Seller shall use its best efforts to minimize the
assignment of such Major Equipment to areas outside Area C.
	 
	 	(d)	 	If in any Year Seller uses any Major Equipment
that is dedicated to a mining area other than Area C (e.g., so that
such Major Equipment is not Capital Equipment or otherwise taken into
account in the determination of the Base Price) to produce coal in Area
C for delivery to Buyers under this Agreement during such Year, then
the Fixed Charge for such Year shall be increased by an amount equal to
the number of hours during which such Major Equipment was operated to
produce coal delivered to Buyers under this Agreement during such Year,
multiplied by the property taxes and depreciation allocable to such
Major Equipment for such Year, and divided by the total number of hours
such Major Equipment was operated during such Year.
	 
	 	(e)	 	In no event shall any of the following costs be
included in the Price or otherwise allocated to Buyers: (i) costs
incurred in connection with moving any Capital Equipment out of or
returning to Area C in connection with the use of such Capital
Equipment outside of Area C; or (ii) any Operating Costs allocable to
the operation of Capital Equipment outside of Area C. If Seller uses
any Major Equipment that is dedicated to a mining area other than Area
C to produce coal in Area C for delivery to Buyers under this

2

 

	 	 	 	Agreement, Buyers shall pay as part of the Commodity Charge the
reasonable costs incurred in connection with moving such Major
Equipment into and out of Area C for the use of such Major Equipment
in Area C and the Operating Costs allocable to the operation of such
Major Equipment in Area C, all multiplied by the number of tons of
coal produced in Area C for delivery to Buyers under this Agreement
using such Major Equipment, and divided by the total number of tons
of coal produced in Area C using such Major Equipment.
	 
	 	(f)	 	The credits described in subsections 1.2 (a),
(b) and (c) shall be applied prior to the application of production
taxes and royalties.
	 
	 	(g)	 	For purposes of this subsection 1.2, the
following terms shall have the following meanings: (i) “Capital
Equipment” means equipment and facilities the cost of which is taken
into account in the determination of the Fixed Charge; (ii) “Major
Equipment” means any item of equipment for which Seller maintains
hourly use records (including, but not limited to, all draglines,
shovels, coal drills, scrapers, dozers, haulers, shops and facilities,
but excluding pick-up trucks, tools and similar items); and (iii)
“Operating Costs” means the costs described in items (b), (c), (d),
(e), (f), (g) and (l) of subsection 3.1, taking into account Seller’s
operating experience as contemplated by subsection 3.3.

     1.3.

     At the end of each calendar year beginning with 1986, if the tonnage of coal taken by Buyers
during said Year, together with the tonnage of coal sold to third parties produced from that
portion of the equipment and facilities dedicated to the performance of this Agreement, is less
than [**] tons (as adjusted for Force Majeure, if any), Buyers shall reimburse Seller, in
addition to the Price, as adjusted pursuant to Section 3, for its reasonable additional costs
incurred in connection with its obligations hereunder and not reimbursed by other sales of coal
produced from the mining operation supplying this Agreement; provided, however,
that the total amount paid pursuant to subsections 1.1 and 1.3, plus the amount received by
Seller from such other sales of coal produced from the portion of the equipment and facilities
dedicated to the performance of this Agreement, together with appropriate adjustments for Force
Majeure, if any, shall not exceed the amount which would have been paid if [**] tons had been
taken during said Year by Buyers. For the purpose of this Section 1, Seller shall be deemed to have
delivered and Buyers shall have taken delivery of not less than one (1) ton of coal per month.

     1.4.

     If, because of Force Majeure, Seller is unable to deliver, or Buyers are unable to take, all
of the coal ordered pursuant to an Approved Annual Operating Plan, the depreciation portion of the
Fixed Charge (1.1(a)), as adjusted pursuant to Section 3, for coal delivered during the

3

 

calendar year in which said Force Majeure occurred shall be computed as though all the coal
ordered was delivered and the Force Majeure had not occurred. Any difference between the amount
actually paid for coal delivered during the Year affected by Force Majeure, and the amount actually
due by applying the provisions of this subsection 1.4, shall be promptly credited or debited to the
Buyers.

2. ADJUSTMENT FOR BTU CONTENT

     2.1.

     The Base Price of coal delivered prior to January 1, 1999 shall be subject to the Adjustment
for Btu content as provided in this subsection 2.1. The Price specified in subsection 1.1, or as
hereafter adjusted, is for coal having a calorific content of [**] Btu/lb as received. Whenever
the weighted average calorific value of coal delivered hereunder during any Year, as determined by
the analyses described in Section 11 of this Agreement, varies by more than [**] Btu/lb over or
below [**] Btu/lb, the applicable price per ton to be paid for coal delivered during such Year
shall, because of such fact, be adjusted as follows:

	 	(a)	 	Compute the average price per ton for coal
delivered during said Year;
	 
	 	(b)	 	Multiply such price per ton by the average
number of Btu per pound of coal delivered during said Year (as
determined pursuant to Section 10 of this Agreement);
	 
	 	(c)	 	Divide (b) by [**] Btu; and
	 
	 	(d)	 	The amount determined in (c) is the adjusted
price per ton for coal delivered during said Year.

     2.2.

     Any difference between amount actually paid for coal delivered during said Year and the amount
actually due by applying the adjusted price shall promptly be debited or credited to the Buyers or
Seller, as the case may be.

3. ADJUSTMENTS FOR COST CHANGES

     3.1.

     The Price shall be adjusted from time to time to reflect actual changes in the cost to Seller,
including Seller’s contractors and agents, of land reclamation, mining, selling and delivering the
coal hereunder in items (a) through (m) hereinafter set forth. Such adjustments when determined
shall be applied to the Fixed Charge (1.1(a)) and to the Commodity Charge (1.l(b)) as may be
appropriate- The items are as follows:

	 	(a)	 	[**] for [**] ;

4

 

	 	(b)	 	[**] of [**] and/or [**] for [**] ;
	 
	 	(c)	 	[**] on [**] of [**] into a [**] and
[**] or any [**] or [**] or [**] ;
	 
	 	(d)	 	[**] and [**] for [**] ;
	 
	 	(e)	 	[**] of [**] to or for the [**] of [**]
for [**] to or for the [**] of [**] , to the extent that such [**]
with or are [**] with or [**] to [**] or [**] with the [**]
or any [**] ;
	 
	 	(f)	 	[**] ;
	 
	 	(g)	 	[**] and other [**] by [**] or by [**] to
the extent [**] ;
	 
	 	(h)	 	[**] of [**] to [**] and [**] , provided,
however, that the [**] and the [**] of which [**] ;
	 
	 	(i)	 	[**] and [**] including [**] , other than t
[**] by or [**] ; and [**] or [**] other than [**] to the
extent [**] of the [**] ;
	 
	 	(j)	 	[**] to [**] based on [**] of [**]
hereunder;
	 
	 	(k)	 	[**] for [**] , the [**] of which [**] by
[**] from time to time, [**] with [**] as applied to the [**] ;
	 
	 	(l)	 	[**] of [**] and [**] for [**] and [**]
except [**] , and;
	 
	 	(m)	 	[**] for [**] .

     3.2. Method of Calculating Adjustments.

     Whenever a change occurs in any of the items of cost referred to in items (a) through (m) of
subsection 3.1, the amount of the change resulting therefrom in the actual cost of Seller of land
reclamation, mining, selling and delivering coal hereunder shall be determined and shall be added
to or subtracted from, as the case may be, the Fixed Charge or the Commodity Charge, as may be
appropriate in substitution for and in lieu of all previous revisions in the Price which resulted
from changes in said items. Notwithstanding any other provision of this Agreement to the contrary,
Seller’s actual costs shall be used for purposes of determining adjustments to the Price.

     3.3. Operating Experience.

     Whenever reference is made herein to any period of time to be used as a factor in the
determination of revisions in the Price in accordance with this Section 3, it has been assumed that
any such period will have been a normal period of operation, and has included, among other things,
consideration of the quantity of coal delivered in relation to the quantity of coal uncovered
during the period; and such period shall be adopted and used unless, in any instance,

5

 

the parties mutually agree that a particular period was not a normal, operating period and
adopt a different period or other period, in which event such different or other period shall be
used, in such instance only, in the determination of revisions in the Price.

     3.4. Adjustments to be Determined Promptly—Limitation.

     When a change occurs in any of the items of cost referred to in items (a) and (k) and the
[**] portion of item (i) of subsection 3.1, the amount of the revision to be made in the Price, by
reason of such change, shall be determined as promptly as possible on the basis of comparison of
normal periods of operation of sufficiently long duration to reflect accurately the actual effect
of any such change; and that revision of such Price shall be retroactive to the date of the
occurrence of the chance resulting in that revision. All sums owing by reason of revisions being
thus retroactive shall be paid upon submission of proper invoice therefor. With regard to changes
in the costs described in items (b), (c), (d), (e), (f), (g), (h), (i), (j), (l) and (m) of
subsection 3.1, the Price shall be revised as of March 1 and September 1 of each            year.

     3.5. Procedures for Implementation of Price Adjustments.

	 	(a)	 	Whenever Seller knows or has reason to believe
there will be a change in any items of cost for which an adjustment to
the Price is to be made pursuant to subsection 3.1, Seller shall
promptly advise Buyers thereof even though the amount of such change is
not then known to Seller without limiting the generality of the
foregoing, Seller shall use its best efforts to give Buyers written
notice of any adjustment which is to be effective on March 1 of any
Year on or before May 15 of such year and written notice of any
adjustment which is to be effective on September 1 of any Year on or
before November 15 of such Year. Any notice by Seller under the
preceding sentence shall be accompanied by a detailed explanation of
the reasons for the proposed adjustment (including, but not limited to,
reference to the particular provisions of this Agreement pursuant to
which the adjustment is to be made and an itemization of the cost
changes giving rise to the adjustment). Seller shall provide such
additional information as the Buyers may reasonably request to verify
the proposed adjustment. Seller’s and Buyers’ respective books and
records pertaining to any proposed adjustment shall be subject to
examination by the other pursuant to subsection 21.2 of this Agreement.
	 
	 	(b)	 	If Seller gives notice of any adjustment under
subsection 3.5(a), Buyers shall use their best efforts to complete any
examination and audit of Seller’s books and records required to verify
the adjustment and give Seller a written response to Seller’s proposal
for adjustment within forty-five (45) days after Buyers’ receipt of the
notice.

6

 

	 	(c)	 	Unless otherwise agreed by the Buyers and
Seller, any portion of a proposed adjustment to the Price under this
subsection 3.5 which is agreed upon by the Buyers and Seller shall be
implemented effective as of the applicable March 1 or September 1. The
Buyers and Seller shall each use their best efforts to promptly resolve
any portion of the proposed adjustment which is in dispute. Upon
request of the Buyers or Seller, each party shall designate a
representative with the responsibility and authority to represent such
Party in the resolution of the dispute. Such representatives shall
meet, as soon as practicable and in no event later than thirty (30)
days after the request of any party, at a mutually acceptable time and
location to negotiate a mutually acceptable resolution of the dispute.
If within thirty (30) days after the date of such meeting (or such
longer period as may be agreed upon by the parties), such
representatives do not reach a mutually acceptable resolution of the
dispute, then any party may submit the dispute for resolution pursuant
to arbitration under Section 8.3 of this Agreement.
	 
	 	(d)	 	Pending resolution of any dispute pursuant to
subsection 3.5(c) (e.g., by agreement or arbitration), each Buyer shall
elect to either (i) pay Seller’s invoices under subsection 1.2 as if
the disputed portion of the proposed adjustment had been agreed upon or
(ii) withhold payment of any invoice to the extent based upon the
disputed portion of the proposed adjustment until resolution of the
dispute.
	 
	 	(e)	 	If any Buyer pays a disputed amount under
subsection 3.5(d)(i) and it is later determined that such amount was
not due and payable (e.g., in the event that the proposed adjustment is
not required under subsection 3.1 ), Seller shall immediately refund to
such Buyer the amount that was overpaid, together with interest thereon
from the date paid by such Buyer until the date refunded by Seller.
	 
	 	(f)	 	If any Buyer withholds any disputed amount
under subsection 3.5(d)(ii) and it is later determined that such amount
was properly due and payable (e.g., in the event that the proposed
adjustment is required under subsection 3.1 ), then such Buyer shall
immediately pay such amount to Seller, together with interest thereon
from the date such amount was due (e.g., pursuant to subsection 1.2)
until the date paid.
	 
	 	(g)	 	Interest under subsections 3.5(e) and (f) shall
be computed at the prime rate quoted from time to time by Citicorp or
such other financial institution as may be agreed upon by the parties,
computed monthly and compounded semi-annually.

7

 

     3.6. Limitation on Amount of Adjustment.

     The production, sale and delivery of coal to Buyers under this Agreement shall at all times be
conducted efficiently and economically and in such a manner that any increase in the cost thereof
to Buyers will be kept to minimum consistent with good operating practices. Payments made for
overtime (except “customary overtime”) solely for the purpose of accomplishing the production and
delivery of the coal in the quantity and at the rate of delivery called for by this Agreement shall
not be considered in computing revision of the Price as aforesaid. As used herein, “customary
overtime” means time (in excess of straight time) required by wage contracts to be worked or which
is worked in the usual and normal operations of the majority of the mines in mining districts west
of the Mississippi River.

     3.7. No Adjustments Because of Certain Tax Changes.

     Nothing in this Section 3 contained shall be construed as authorizing or providing for
revisions of the Price based on changes in federal, state or local taxes imposed on or measured by
net income.

     3.8. Adjustments Because of Inflation or Deflation.

     The Price shall also be revised to compensate for the effects of inflation and/or deflation on
Seller’s profit per ton under this Agreement as follows:

	 	(a)	 	For the purpose of computing such revision, the
Parties will use the [**] on the adjusted base that the average cost
of all items therein for the year [**] = [**] , and, if said base is
revised or a new base adopted for said Index, then the revised or new
Index must be adjusted to said base of [**] = [**] . The index
number for all items in said Index for [**] , [**] , is not yet
available from the Federal Government, but this index number, when
available, shall be used as the basis for computing the amount of any
such revisions; and
	 
	 	(b)	 	Whenever a change occurs from said index
number, the Commodity Charge (1.1(b)) shall be increased or decreased
by $ [**] per ton for each one point change above or below said index
number. Such adjustment shall be made as of March 1 and September 1 of
each year or whenever the Consumers Price Index changes by [**] ,
whichever occurs first.

4. IMPACT OF FORCE MAJEURE PRIOR TO JULY 1, 2000

     4.1.

     If Buyers’ generating plant is rendered inoperable as the result of physical damage,
legislation or lawful regulation of governmental body, court order or other causes of a similar
nature that prevent that further operation of the generating plant, and if the Buyers have notified
Seller in writing that the plant will not be restored, rebuilt or otherwise made operable, then

8

 

Seller’s obligation to deliver and Buyer’s obligation to take and pay for coal, including
Fixed Charges (1.1(a)), shall terminate as of the date provided in the notice; provided, however,
that the Buyers shall be liable to Seller for any loss (other than royalties or loss of profits)
sustained by Seller as a result of such termination of deliveries, and Seller shall use all
reasonable efforts to minimize any such loss.

     4.2.

     Buyers’ obligation to pay the depreciation portion of Fixed Charges (1.1(a)) shall be suspended or
reduced after three months of continuous interruption of curtailment of deliveries because of a
Force Majeure affecting Buyers or Seller. Depreciation paid during any Years when deliveries are
interrupted or curtailed because of a Force Majeure shall be subject to adjustment pursuant to
subsection 1.4.

9

 

EXHIBIT B1—REVISED SAMPLE CALCULATIONS

(a)      [**]

     A x C                -   D    =    E

           B

     where:

A=            [**]

B=            [**]

C=            [**]

D=           [**]

E=           [**]

     (i)      [**]

          (1)      [**]

     Example Calculation:                 A – B = C

     where:

A =           [**]

B=           [**]

C=           [**]

10

 

If the change in cost is negative, a downward adjustment will be made regardless of whether the
[**] has exceeded the [**] in a prior period. If the change in cost is positive, the fixed cost
will be increased by the amount of the change.

11

 

EXHIBIT C

DESCRIPTION OF AREA C

[Map]

 

 

EXHIBIT D

Part 1

Determination of Tonnage Increase

The “Tonnage Increase” (i.e., the additional tons that Buyers purchase to compensate for
the lower BTU content of coal delivered to the Point of Delivery) shall be computed as follows:

AdT = (( [**]                –                AcBtu)/ [**] ) x                AcT

Where:

“AdT” is the additional tons purchased by the Buyers, rounded to the nearest ton (the “Tonnage
Increase”);

“AcBtu” is the actual weighted average Btu content per pound of coal delivered during the Year; and

“AcT” is the actual tonnage delivered to the Buyers during the Year.

For example, if the actual Btu content of coal is [**] Btu/lb. and the actual tonnage delivered
is [**] , then the Tonnage Increase shall be [**] tons.

Part 2

Example Computations of Btu Price Adjustment

	A.	 	Assume that the Approved Operating Budget sets the Variable Cost for a given Year at $ [**]
per ton and the projected Btu content of the coal to be delivered in that Year at [**]
Btu/lb. This produces a budgeted Variable Cost per MMBtu of $ [**] . If the actual Variable
Cost per MMBtu for this Year is $ [**] per MMBtu (i.e., higher than the Variable Cost
per MMBtu specified in the Approved Operating Budget) and the actual Btu content of the coal
is [**] Btu/lb (i.e., lower than [**] Btu/lb) and the actual tonnage delivered to the
Buyers is [**] , then the Buyers will receive a price adjustment credit equal to the Variable
Cost per Ton multiplied by [**] , with the resulting figure multiplied by the Tonnage
Increase (i.e., $ [**] per ton multiplied by [**] = $ [**] , multiplied by [**]
tons = $ [**] .) (Note that for purposes of determining the Btu price adjustment, the
budgeted Variable Cost per MMBtu is used and not the actual Variable Costs. However, the
difference between budgeted and actual Variable Costs will be considered in determining the
Earned Portion of the Incentive Fee Per Ton.)

	B.	 	If the budgeted Btu/lb were lower than the actual Btu/lb, but the actual Btu/lb were lower
than [**] Btu/lb and the actual Variable Cost per MMBtu was greater than the budgeted
Variable Cost per MMBtu, there would be a Btu price adjustment. For example, assume that the
budgeted Variable Cost of coal is $ [**] per ton and that the budgeted Btu level is [**]
Btu/lb. This produces a budgeted Variable Cost per MMBtu of $ [**] . Further, assume that
the actual Btu level is [**] Btu/lb but that the actual cost per ton is $ [**] ,

1

 

	 	 	thereby resulting in an actual Variable Cost per MMBtu of $[**] .
Because the actual Btu level is less than [**] Btu/lb. and the actual
delivered Variable Cost per MMBtu is greater than the budgeted Variable
Cost per MMBtu, a BTU price adjustment will be made. The Tonnage
Increase is

AdT = (( [**]                 –                 [**] )/ [**] ) x                 [**] tons

AdT = [**] tons

When the Tonnage Increase is multiplied by $ [**] ($ [**] x [**] ), the resulting price
adjustment is $ [**] .

2

 

EXHIBIT E

ENTECH, INC. INDEMNIFICATION AGREEMENT

     THIS INDEMNIFICATION AGREEMENT (“Indemnification Agreement) is made as of this 24th
day of August, 1998, by ENTECH, INC., a Montana corporation (“Indemnitor”), in favor of THE MONTANA
POWER COMPANY, a Montana corporation (“Montana”), PORTLAND GENERAL ELECTRIC COMPANY, an Oregon
corporation, (“Portland”), THE WASHINGTON WATER POWER COMPANY, a Washington corporation (“Water
Power”), and PACIFICORP, an Oregon corporation (“Pacific”).

RECITALS

     A. Western Energy Company, a Montana corporation (“Western”) is a wholly-owned subsidiary of
Indemnitor.

     B. Western and Montana, Water Power, Portland, and Pacific are parties to the Amended and
Restated Coal Supply Agreement dated of even date herewith (the “Amended and Restated CSA”).
Together, Montana, Water Power, Portland and Pacific shall be referred to herein as “Indemnified
Parties.” Capitalized terms used herein and not otherwise defined shall have the meanings set
forth in the Amended and Restated CSA.

     C. As owner and operator of the Mine, Western has certain reclamation obligations with respect
to the Mine, including Area C. Under the Original Coal Supply Agreement, Indemnified Parties had
certain contractual obligations to Western to reimburse it for final reclamation costs of Area C.
Indemnified Parties are released from all such obligations, as well as any existing or new
obligations to Western that may be imposed upon Western or Indemnified Parties by federal or state
law or otherwise, pursuant to the provisions of Section 15 of the Amended and Restated CSA,
including the provisions relative to this Indemnification Agreement.

     D. Indemnitor will derive substantial benefit and advantage from the Amended and Restated CSA
and it will be in the Indemnitor’s direct interest and economic benefit to assist Western in
entering the Amended and Restated CSA.

AGREEMENT

     NOW, THEREFORE, for and in consideration of the premises and in order to induce the
Indemnified Parties to enter into the Amended and Restated CSA and for other good and valuable
consideration, the receipt and sufficiency of which are hereby acknowledged, the Indemnitor agrees
as follows:

     1. Indemnification of Indemnified Parties. Indemnitor agrees to indemnify and hold
harmless each Indemnified Party together with their successors, assigns, officers, directors,
employees and affiliates from and against any and all claims, damages, losses, liabilities and
expenses, joint or several, arising from or relating to Subsection 15.2 Final Reclamation
including, without limitation, the assertion and final determination of any claim or liability
against the Indemnified Parties (or any of them) by any person or entity for expenses or costs of

1

 

Subsection 15.2 Final Reclamation, arising under any applicable federal or state law, or otherwise.

     2. Defense of Claims. If any legal proceeding shall be instituted, or any claim or
demand made, against any Indemnified party in respect of which Indemnitor may be liable hereunder,
such Indemnified Party shall give prompt written notice thereof to Indemnitor and Western.
Indemnitor shall have the right to defend any litigation, action, suit, demand, or claim for which
indemnification is being sought and such Indemnified Party shall extend reasonable cooperation in
connection with such defense, which shall be entirely at Indemnitor’s expense. in the event
Indemnitor fails to defend the same within a reasonable length of time and upon written notice by
Indemnified Parties to Indemnitor and Western, the Indemnified Parties shall be entitled to assume
the defense thereof, and Indemnitor shall repay the Indemnified Parties for all expenses reasonably
incurred in connection with said defense (including reasonable attorney’s fees and settlement
expenses).

     3. Representations and Warranties of Indemnitor. Indemnitor represents and warrants
to each of the Indemnified Parties that (i) it is a corporation duly organized, validly existing
and in good standing under the laws of Montana, (ii) it has full corporate and legal power to enter
into this Indemnification Agreement and to authorize the indemnification under the terms of the
Agreement, and (iii) this Indemnification Agreement constitutes a legal, valid and binding
obligation of Indemnitor enforceable against it in accordance with its terms.

     4. Amendment and Waiver. Neither this Indemnification Agreement not any of the
provisions herein may be changed, waived or terminated except by the prior written consent of the
parties hereto.

     5. Successors and Assigns. This Indemnification Agreement is binding upon and shall
inure to the benefit of the successors and assigns of the parties hereto, subject to the provisions
of Section 15 of the Amended and Restated CSA.

     6. Governing Law. The parties to this Indemnification Agreement are domiciled in
three different states. In order to create greater certainty with respect to their legal rights in
obligations under this Indemnification Agreement, the parties desire to adopt as the substantive
law of this Indemnification Agreement the law of a state which has highly developed commercial law
and precedent and which is not the domicile of any of the parties. The parties therefore agree
that this Indemnification Agreement shall be subject to and governed by the substantive laws of the
state of New York as though this Indemnification Agreement were performed in full
within the state of New York, but without giving effect to New York principles of conflicts of
laws.

2

 

     8. Limitation on Third-Party Beneficiaries. This Indemnification Agreement is only
intended to benefit the Indemnified Parties, their officers, directors, employees, affiliates and
their permitted successors and assigns and may not be relied upon or enforced or exercised by any
other person or entity.

	 	 	 	 	 
	ENTECH, INC.	 	 
	 
	 	 	 	 
	By:

	 	/s/ E. M. Senechal
 

	 	 
	Its:

	 	V.P. and Treasurer	 	 
	 

	 	 	 	 

3exv10w2

 

Exhibit 10.2

COAL TRANSPORTATION AGREEMENT

     THIS AGREEMENT, is entered into as of this 10th day of July, 1981, between THE MONTANA POWER
COMPANY (“Montana”), a Montana corporation of Butte, Montana, and PUGET SOUND POWER & LIGHT COMPANY
(“Puget”), a Washington corporation of Bellevue, Washington, and Puget Colstrip Construction
Company (“PCCC”), a Washington corporation of Bellevue, Washington, and THE WASHINGTON WATER POWER
COMPANY (“Water Power”), a Washington corporation of Spokane, Washington, and PORTLAND GENERAL
ELECTRIC COMPANY (“Portland”), an Oregon corporation of Portland, Oregon, and PACIFIC POWER & LIGHT
COMPANY (“Pacific”), a Maine corporation of Portland, Oregon, and BASIN ELECTRIC POWER COOPERATIVE,
a North Dakota cooperative corporation of Bismarck, North Dakota (“Basin Electric”); and WESTERN
ENERGY COMPANY, a Montana corporation of Butte, Montana (“Western”). Montana, Puget, PCCC, Water
Power, Portland, Pacific, and Basin Electric are sometimes herein referred to collectively as
“Plant Owners” and individually as “Plant Owner.”

RECITALS

     A. Plant Owners will construct, own and operate a coal fired steam-electric generating plant
near Colstrip, Montana, consisting of two 700 megawatt nominal rating generating units known as
Colstrip Units #3 and #4 (the “Generating Plant”). The first unit is planned to be in commercial
operation on or about January 1, 1984, and the second on or about January 1, 1985.

     B. Pursuant to the Ownership and Operation Agreement of Colstrip Units #3 & #4 (the “Ownership
Agreement”) entered into as of May 6, 1981, by the Plant Owners, each Plant Owner has an initial
share (as the same may be changed pursuant to the Ownership Agreement, “Project Share”) of the
Generating Plant as follows:

	 	 	 
	Montana
	 	27.9%
	Puget/PCCC
	 	23.25%
	Portland
	 	18.6%
	Water Power
	 	13.95%
	Pacific
	 	9.3%
	Basin Electric
	 	7.0%

     C. Plant Owners and Western have entered into a Coal Supply Agreement dated July 2, 1980 (as
amended, the “Coal Contract”) for the sale and delivery of coal for the Generating Plant. Pursuant
to Subsection 4.1 of the Coal Contract, coal sold under the Coal Contract will be delivered to
Plant Owners at the western end of the coal Conveyor system (as the same may be extended from time
to time, the “Point of Delivery”) to be constructed by Western for the transport of coal from
Western’s mining area known as Area C (“Area C”) to the Generating Plant. The Point of Delivery
shall initially be located near the eastern boundary of Area C approximately 4.46 belt miles west
of the Generating Plant as shown on Exhibit 1 to the Coal Contract.

     D. The parties desire to establish terms and conditions relating to the transportation of coal
from the Point of Delivery to Generating Plant.

 

 

     NOW, THEREFORE, in consideration of the mutual covenants and agreements herein stated, and the
performance thereof, the parties hereto agree as follows:

1 — TRANSPORTATION OF COAL

     1.1 Western shall transport all coal sold under the Coal Contract from the Point of Delivery
to the Generating Plant. As used elsewhere in this Agreement, the word “transport” means transport
from the Point of Delivery to the Generating Plant.

     1.2 Without limiting the generality of Subsection 1.1, Western shall design, construct, own,
operate and maintain a coal Conveyor system (as the same may be extended from time to time, the
“Conveyor”) for the transport of coal sold under the Coal Contract (“Contract Coal”). The Conveyor
from the Generating Plant to the initial Point of Delivery shall be constructed along the route
shown on Exhibit 1 to this Agreement and shall be extended only with the prior written consent of
Plant Owners. Western agrees to extend its best effort to complete construction of the Conveyor
from the Generating Plant to the initial Point of Delivery no later than July 1, 1983.

     1.3 Western shall not use any means other than the Conveyor to transport Contract Coal, except
to the extent that use of such other means is required:

	 	(a)	 	as a result of damage, malfunction or inoperability of the Conveyor;
	 
	 	(b)	 	to perform necessary maintenance or repair of the Conveyor;
	 
	 	(c)	 	to transport initial quantities of coal if construction of the Conveyor is not
completed by July 1, 1983; or
	 
	 	(d)	 	by written direction given to Western by Plant Owners.

In the event Western is unable to transport coal by means of the Conveyor for these reasons, and if
alternate means of transportation are reasonably available, Plant Owners agree to include the costs
associated with the alternate means of transportation in the calculation of the cost reimbursement
charge provided for, in Subsection 5.4 herein. Western agrees to extend its best efforts to
transport coal by an alternate means of transportation in the event it is required.

     1.4 Western shall not, without the prior written consent of the Plant Owners, use the Conveyor
for any purpose other than to transport Contract Coal.

2 — TERM

     2.1 This Agreement shall be effective and binding when executed by Montana, Puget, PCCC, Water
Power, Portland, Pacific and Western and shall be effective and binding as to Basin Electric only
when executed by Basin Electric. This agreement shall continue for so long as the Coal Contract
continues.

-2-

 

     2.2 Transportation of coal under this Agreement is expected to begin on or about July 1, 1983.

     2.3 If the Plant Owners require coal transportation service from Area C to the Generating
Plant after expiration of the Coal Contract, this Agreement will be extended on terms mutually
agreeable to Western and the Plant Owners, reflecting then existing conditions.

3 — QUANTITY AND SCHEDULING

     3.1 At least ninety (90) days prior to the estimated date of the initial testing of the first
unit of the Generating Plant, Plant Owners shall notify Western, pursuant to Subsection 3.1 of the
Coal Contract, of the amount of coal Plant Owners will require for testing and for the coal storage
pile for the Generating Plant. Western shall transport such amount of coal within sixty (60) days
after the receipt of such notice.

     3.2 At least thirty (30) days prior to the estimated date of the commencement of operations of
the first unit of the Generating Pant, Plant Owners shall notify Western, pursuant to Subsection
3.2 of the Coal Contract, of the amount of coal Plant Owners will require from such date of
commencement of operations until the date that transport of coal commences pursuant to Subsection
3.5. Western shall transport said coal as requested by Plant Owners during such period. For the
purposes of this section, “date of commencement of operations” shall be the date determined by
Plant Owners with respect to each unit.

     3.3 At least ninety (90) days prior to the estimated date of initial testing of the second
unit of the Generating Plant, Plant Owners shall notify Western, pursuant to Subsection 3.4 of the
Coal Contract, of the amount of additional coal Plant Owners will require for testing and for the
coal storage pile for the Generating Plant. Western shall transport such amount of coal within
sixty (60) days of the receipt of such notice.

     3.4 At least thirty (30) days prior to the estimated date of the commencement of operations of
the second unit of the Generating Plant, Plant Owners shall notify Western, pursuant to Subsection
3.5 of the Coal Contract, of the amount of coal Plant Owners will require from such date of
commencement of operations until the date that transportation of coal commences pursuant to
Subsection 3.6. Western shall transport said coal as requested by Plant Owners during such period.

     3.5 During the period from the date of commencement of operations of the first unit of the
Generating Plant until the date of commencement of operations of the second unit of the Generating
Plant, Western’s obligation will be to transport the Plant Owners’ coal requirements as specified
in purchase orders under Subsection 3.3 of the Coal Contract.

     3.6 Upon the date of commencement of operations of the second unit of the Generating Plant,
Western’s obligation will be to transport the Plant Owners’ requirements as specified in purchase
orders under Subsections 3.4 and 3.6 of the Coal Contract.

     3.7 Western and the Plant Owners shall, to the extent reasonably feasible, cooperate in
scheduling daily, weekly and monthly coal transportation in order to accommodate Plant

-3-

 

Owners’ changing fuel requirements. Said parties shall also cooperate in the same manner in
notifying each other in advance of scheduled outages or downtime in order to avoid unnecessary
inconvenience and delay and to facilitate efficient use of said downtime by each party and to the
extent reasonably possible to assure Plant Owners of an opportunity to increase its stock pile of
coal for use during downtime of the Conveyor. Subject to these reciprocal obligations, Western
shall maintain the capability of making continuous coal deliveries to Plant Owners within the
design limitations of Plant Owners’ coal receiving facilities.

4 — WEIGHING

All coal transported hereunder shall be weighed pursuant to Subsection 4.2 of the Coal Contract and
these weights shall be used for billing purposes under this Agreement.

5 — BASE PRICE AND PAYMENT

     5.1 The Base Price to be paid by the Plant Owners for the transportation of coal by Western
hereunder shall be the price computed from the sum of (a), (b), and (c), and reduced by (d), in
this Subsection:

          (a) Fixed Charge — An annual charge for depreciation, reimbursement of property tax
and overhead costs associated with the Conveyor;

          (b) Cost Reimbursement Charge — A per ton charge for the actual costs to operate and
maintain the Conveyor and to transport coal under this Agreement by means other than the Conveyor;
and

          (c) Fee — Operating Profit — A per ton charge as an operating profit for the
construction, Ownership, operation and maintenance of the Conveyor; less

          (d) Revenue Credit — A monthly credit for any revenues received on account of uses of
the Conveyor for purposes other than to transport Contract Coal.

     5.2 The Fee — Operating Profit and the depreciation and property tax components of the Fixed
Charge to be included in the Base Price shall be calculated from Western’s actual initial
investment in the Conveyor. Western’s actual initial investment shall include the following
expenditures reasonably incurred by Western to construct the Conveyor from the Generating Plant to
the initial Point of Delivery:

          (a) All expenditures for right-of-way acquisition for the Conveyor, excluding expenditures for
land and/or lease rights made by Western prior to January 1, 1981;

          (b) All expenditures for preliminary investigation and development costs, architectural and
engineering fees and expenses, contractors’ fees, labor, materials, equipment and supplies,
operator and other personnel training, testing, permits and license fees and costs, legal costs,
permitting costs, and all other costs properly allocable to construction of the Conveyor;

-4-

 

          (c) All expenditures for insurance and interest during construction associated with the
construction of the Conveyor; and

          (d) All expenditures for any modification to Western’s facilities in mining Areas A, B or E of
its Rosebud Mine which are required by any state or federal agencies as a condition or stipulation
of approval of the permits required for the Conveyor.

On January 1, 1984, Western will provide the Plant Owners with an accounting summary of its
investment in the Conveyor. The Plant Owners will have until July 1, 1984 to audit Western’s
financial records and to reach agreement with Western on the actual amount of initial investment.
The amount so agreed upon shall be the “Initial Investment.” For the purpose of this Agreement,
regardless of the method of equipment procurement or financing used by Western (including, but not
limited to, leveraged leasing), the amount of Initial Investment shall be the actual capital
expenditures for the equipment dedicated by Western to the fulfillment of this Agreement.

     5.3 The Fixed Charge component of the Base Price shall be determined as follows:

          (a) The depreciation component of the Fixed Charge shall be determined from the Initial
Investment by using straight line methods consistent with generally accepted industry accounting
principles as recognized by Western’s independent auditors who shall be of national reputation.

          (b) The property tax component of the Fixed Charge shall be the actual ad valorem taxes paid
by Western as determined by applying the then current ad valorem tax levy rate against the taxable
value of Western’s property included in the Initial Investment.

          (c) The overhead component of the Fixed Charge shall be a reasonable overhead which on the
date hereof is agreed to be twenty percent (20%) of the annual compensation, including payroll
additives and fringe benefits, paid to Western’s employees engaged exclusively in the operation and
maintenance of the Conveyor.

The Fixed Charge shall be an annual charge to be paid in monthly installments at the rate of
one-twelfth (1/12) of the amount as determined herein.

     5.4 The Cost Reimbursement Charge component of the Base Price shall be the actual costs
reasonably incurred by Western to operate and maintain the Conveyor or to transport coal under this
Agreement by means other than the Conveyor, including the cost of all direct labor, payroll
additives and fringe benefits, electric power, tools, equipment, materials and supplies,
replacement spare parts, contract maintenance, bonds and permits, insurance, and other expenses
directly attributable to the operation of the Conveyor and all taxes of whatever kind (except taxes
imposed on or measured by net income) paid by Western as a result of owning or operating the
Conveyor; provided, however, that the Cost Reimbursement Charge shall not include any cost or
expense included in (or taken into account in computing) any other component of the Base Price. For
example, the Cost Reimbursement Charge shall not include any expenditure included in the Initial
Investment, ad valorem taxes, overhead or investment described in Subsection 6.2 or 6.4.

-5-

 

     5.5 The Fee — Operating Profit component of the Base Price shall be determined in the
following manner: The amount of Initial Investment shall be divided by the maximum annual tonnage
to be transported (i.e.: 6,000,000 tons). The quotient thus obtained shall be multiplied by twenty
nine and one-half percent (29.5%) to obtain the Fee — Operating Profit amount of the Base Price.

     5.6 The Revenue Credit for any month shall be equal to the amount of any revenues received
during such month on account of uses of the Conveyor for purposes other than to transport Contract
Coal.

     5.7 Notwithstanding any other provision of this Agreement to the contrary, the Base Price
under this Agreement shall not include any charge or amount for any cost or expense included in, or
taken into account in the determination of, the Base Price for coal delivered under the Coal
Contract.

     5.8 Within fifteen (15) days after the end of each calendar month after the later of July,
1983 or the month during which the construction of the Conveyor is completed, Western shall submit
to each Plant Owner an invoice for such Plant Owner’s share of the Base Price equal to:

where:

	 	 	 	 	 	 	 
	 

	 	FC
	 	=
	 	Fixed Charge
	 
	 	 	 	 	 	 
	 

	 	CRC
	 	=
	 	Cost Reimbursement Charge
	 
	 	 	 	 	 	 
	 

	 	FOP
	 	=
	 	Fee — Operating Profit
	 
	 	 	 	 	 	 
	 

	 	RC
	 	=
	 	Revenue Credit
	 
	 	 	 	 	 	 
	 

	 	PS*
	 	=
	 	such Plant Owner’s Project Share
	 
	 	 	 	 	 	 
	 

	 	POT**
	 	=
	 	the number of tons of Contract Coal transported under this Agreement for
such Plant Owner during the applicable month
	 
	 	 	 	 	 	 
	 

	 	TT**
	 	=
	 	the total number of tons of Contract Coal transported for all Plant Owners
during the applicable month

 

			
	*	 	The Plant Owners will promptly notify Western of any change in any Plant Owner’s Project
Share pursuant to the Ownership Agreement.
	 
	**	 	For purposes of determining each Plant Owner’s share of the Cost Reimbursement Charge for
any month during which no Contract Coal is transported hereunder, each Plant Owner shall be
deemed to have had transported its Project Share of one (1) ton.

-6-

 

Each Plant Owner shall pay its share of the Base Price to Western, at its office at 107 East
Granite, Butte, Montana 59701, within fifteen (15) days after such Plant Owner’s receipt of
Western’s invoice thereof. Each of Western’s invoices shall be supported by such receipts,
documents and other information as any Plant Owner may reasonably request.

     5.9 The Base Price to be computed under the provisions of this section may not be accurately
calculated until July 1, 1984. Transportation of coal is expected to begin approximately one (1)
year earlier. Western and the Plant Owners shall mutually agree on a price to be charged for coal
transported during this interim period and the price will be adjusted to the actual Base Price.

     5.10 At the end of each calendar year beginning with 1986, if the tonnage of coal transported
by Western is less than the “Minimum Annual Tonnage,” as that term is defined in Subsection 7.8(a)
of the Coal Contract (as adjusted for force majeure, if any) Plant Owners shall pay Western, in
addition to the Base Price for all coal transported during that calendar year, the Fee — Operating
Profit component of the Base Price for the number of tons not transported below the Minimum Annual
Tonnage.

     5.11 This Section 5 “Base Price and Payment” and Section 6 “Price Changes” shall be open on
the 20th, 25th and 30th anniversary dates of this Agreement for a renegotiation of Base Price and
for such revisions to the adjustment provisions of Section 6 as are necessary in order to update
the adjustment provisions to the effective date of the renegotiated Base Price. In the event the
parties are unable to agree upon a revised Base Price or upon such revisions of the provisions for
adjustment within six (6) months after any such anniversary date, the Base Price and necessary
revisions to the adjustment provisions shall be determined by arbitration pursuant to Section 11
hereof. Any price so determined by arbitration shall be made effective as of the applicable
anniversary date.

6 — PRICE CHANGES

     6.1 Prior to the beginning of each calendar year beginning with 1986, Western shall notify the
Plant Owners of Western’s best estimate of the Base Price to be charged for the transportation of
coal in the ensuing year.

     6.2 The Depreciation component of the Fixed Charge component of the Base Price shall be
adjusted from time to time to reflect changes in Western’s capital investment properly allocable to
transporting coal under this Agreement. These adjustments shall be made using straight line methods
consistent with generally accepted industry accounting principles as recognized by Western’s
independent auditors.

     6.3 The Property Tax component of the Fixed Charge component of the Base Price shall be
adjusted from time to time to reflect changes in actual ad valorem taxes paid by Western Energy on
any property properly allocable to transporting coal under this Agreement.

     6.4 The Fee — Operating Profit component shall be adjusted in the event Western is required to
make a substantial investment to extend the Conveyor or modify the Conveyor to correct design
deficiencies. For the purpose of this section, a substantial investment shall be

-7-

 

defined as an investment of at least five percent (5%) of the Initial Investment cost of the
Conveyor, except that in the event additional right-of-way acquisition costs are encountered after
the construction of the Conveyor, any such cost so encountered shall be defined as substantial and
will require an adjustment of the Fee -Operating Profit component of the Base Price. In the event
Western is required to make a substantial additional investment, the amount of such investment, as
certified by the Plant Owners’ audit, shall be divided by the maximum annual tonnage to be
transported (i.e.: 6,000,000 tons). The quotient thus obtained shall be multiplied by
twenty-nine and one-half percent (29.5%) to obtain the additional Fee – Operating Profit that shall
be added to the Base Price, effective on the date the substantial additional investment is made.

     6.5 Nothing contained in this Section 6 shall be construed as authorizing, or providing for
revisions of the Base Price based on changes in federal, state or local taxes imposed on or
measured by net income.

     6.6 The Base Price shall also be revised to compensate for the effects of inflation and/or
deflation on Western’s profit per ton under this Agreement as follows:

          (a) For the purpose of computing such revision, the parties will use the Consumers Price Index
(as issued by the United States Department of Labor, Bureau of Labor Statistics) on the adjusted
base that the average cost of all items therein for the year 1967 = 100, and, if said base is
revised or a new base adopted for said Index, then the revised or new Index must be adjusted to
said base of 1967 = 100. The index number for all items in said Index for June, 1983, or the month
in which the construction of the Conveyor is complete, whichever is later, is not yet available
from the Federal Government, but this index number, when available, shall be used as the basis for
computing the amount of any such revisions; and

          (b) Whenever a change occurs from said index number, the Fee -Operating Profit (5.1(c)) shall
be increased or decreased by an inflation/deflation adjustment factor which will increase or
decrease the Base Price per ton for each one point change above or below said index number. Such
adjustment shall be made as of March 1 and September 1 of each year or whenever the Consumers Price
Index changes by one (1) full point, whichever occurs first.

          (c) The inflation/deflation adjustment factor shall be determined by dividing the Fee -
Operating Profit component of the Base Price, as determined in accordance with Subsection 5.5
herein, by the Consumers Price Index value for the month specified in Subsection 6.6(a). The
quotient obtained thereby, expressed as a four (4) decimal dollar value, shall be the adjustment
factor to be used in Subsection 6.6(b).

          (d) In the event that the Fee — Operating Profit is increased in accordance with the
provisions of Subsection 6.4 herein, an additional inflation/deflation adjustment factor to be
applied to such increase will be computed in a manner similar to that provided for in Subsection
6.6(c) above, except that the additional inflation/deflation adjustment factor shall be based on
the Consumers Price Index published for the month in which the required substantial investment is
made.

-8-

 

It is further agreed that if and when said Consumers Price Index has increased by one hundred
percent (100%) or more from the index number for the month specified in Subsection 6.5(a) or has
decreased by fifty percent (50%) or more from said index number for such month then for the
purposes of this Agreement, either party may notify the other that it believes an unusual condition
may have occurred and a gross inequity may have resulted. If a gross inequity has occurred as the
result of such unusual condition, the parties agree to negotiate a new Base Price and provisions
for adjustments for cost changes in order to remedy such gross inequity. Each party hereto shall,
in the case of gross inequity, furnish the other with whatever documentary evidence may be
requested in effecting a fair settlement of such gross inequity.

7 — FACILITY DESIGN

     Western shall develop a design and budget for the Conveyor, including a route lay-out,
equipment selection, structure design and location, and identify any necessary ancillary structures
and equipment, consistent with good engineering practices as observed in the industry. Western and
the Plant Owners shall cooperate in establishing the location and design of the interface
facilities at the terminus of the Conveyor. Within sixty (60) days after the date of this
Agreement. Western shall submit the proposed design and budget to the Operator of the Generating
Plant described in Section 15 of this Agreement. The Operator shall coordinate the review and
approval of the Conveyor design and budget by the Plant Owners. The Plant Owners, through the
Operator of the Generating Plant, shall perform and conduct their review in an expedient manner in
order to avoid delays to either the permitting or construction of the Conveyor. The final design
and budget for the Conveyor shall be subject to the approval of Western and the Plant Owners.

8 — FORCE MAJEURE

     8.1 If, because of force majeure, any party shall be unable to carry out any of its
obligations under this Agreement, then the obligations of such party shall be suspended to the
extent made necessary by such force majeure. The party affected by force majeure shall give notice
to the other parties as promptly as practicable of the nature and probable duration of such force
majeure. The term “force majeure” shall mean acts of God, legislation or lawful regulations of any
governmental body, court orders, acts of the public enemy, riots, strikes, labor disputes, labor or
material shortages, fires, explosions, floods, breakdowns of or damage to plants, mines,
transmission lines, equipment or facilities, interruptions in transportation, embargoes, or other
causes of similar nature which wholly or partially prevent the transportation of Contract Coal by
Western, the receiving or consuming of Contract Coal by Plant Owners, or the operation of the
Generating Plant. Plant Owners and Western shall use all reasonable means of preventing the
occurrence of any of the foregoing. Nothing contained herein shall be construed so as to require a
party to settle any strike or labor dispute in which it may be involved. Any party rendered unable
to fulfill any obligation by reason of force majeure shall exercise due diligence to remove such
inability with all reasonable dispatch.

     8.2 If the Generating Plant is rendered inoperable as the result of physical damage,
legislation or lawful regulation of governmental body, court order or other causes of a similar
nature that prevent further operation of the Generating Plant, and if the Plant Owners have

-9-

 

notified Western in writing that the Generating Plant will not be restored, rebuilt or
otherwise made operable, then Western’s obligation to transport coal under this Agreement and Plant
Owners’ obligation to use and pay for the Conveyor (including, but not limited to, payment of the
Fixed Charges described in Section 5) shall terminate as of the date provided in the notice;
provided, however, that the Plant Owners shall be liable to Western for any loss (other than loss
of profits) sustained by Western as a result of such termination, and Western shall use all
reasonable efforts to minimize any such loss.

9 — WAIVERS AND REMEDIES

     9.1 The failure of any party to insist in any one or more instances upon strict performance of
any of the provisions of this Agreement or take advantage of its right hereunder shall not be
construed as a waiver of any such provisions or their relinquishment of any such right, but the
same shall continue and remain in full force and effect.

     9.2 No default of any party to this Agreement in the performance of any of its covenants or
obligations hereunder which, except for this provision, would be the legal basis for rescission or
termination of this Agreement by any other party hereto, shall give or result in such a right
unless and until the party committing such default shall fail to correct the default within sixty
(60) days or within a reasonable time if not correctable within sixty (60) days after written
notice of claim of such default and a statement setting forth the nature thereof are given to such
defaulting party by the party claiming such default.

     9.3 (a) In the event of the occurrence of one or more of the following events which materially
and adversely affect or will affect the ability of Western to perform hereunder as agreed, Plant
Owners shall have the rights set forth in Subsection 9.3 (b) which rights shall be in addition to
all other rights or remedies provided Plant Owners at law or in equity in the event of a default by
Western:

          (1) Western defaults in the performance of any of its obligations hereunder, which
default adversely affects, or will adversely affect, the transportation by Western of coal
to Plant Owners in the required quantity;

          (2) Western becomes insolvent, or becomes the subject of a petition in bankruptcy,
either voluntarily or involuntarily, or any other proceeding in the Federal Bankruptcy Laws;
or is named in, or Western’s coal mine, buildings, equipment of other facilities are
subjected to, a suit for an appointment of receiver;

     (3) Western becomes delinquent in the performance of any financial obligation; or

     (4) Western commits an anticipatory breach of any of its obligations hereunder.

     Western agrees to promptly notify Plant Owners of any default, financial delinquency or
claimed delinquency, insolvency, or anticipated breach as described above.

-10-

 

          (b) In the event of any occurrence of any of the items set forth in (a) above, Plant Owners
jointly and severally shall have all of the following rights, in addition to those provided at law
or in equity:

          (1) To pay any financial obligations of Western and to recover the amounts of such
payments from Western or offset them against any amounts due from any Plant Owner to
Western;

          (2) To require that Western furnish evidence, in a form satisfactory to Plant Owners,
of financial capability to perform its obligations under this contract;

          (3) To take over the operation of the Conveyor; to take immediate possession of all of
Western’s buildings, facilities and equipment used for the transportation of coal hereunder;
to acquire all of Western’s interest in said buildings, facilities and equipment at their
depreciated book cost, but not exceeding the fair value of such buildings, facilities and
equipment in place, which acquisition shall be subject to any liens or encumbrances of
record; and

          (4) To require Western to invite bids from qualified operators to operate the Conveyor
and perform the obligations of Western under this Agreement for the remainder of its term.

10 — SUCCESSORS AND ASSIGNS

     10.1 This Agreement shall inure to the benefit of and be binding upon the parties hereto and
their respective successors and assigns. This Agreement may be assigned and transferred by the
Plant Owners only as set forth in Subsection 10.2 herein and may be assigned and transferred by
Western only as set forth in Subsection 10.3 herein, and not otherwise.

     10.2 The undivided interest of Plant Owners, or any of them, in this Agreement or any part
thereof may be transferred or assigned to a third party only in conjunction with an assignment or
transfer to said third party by Plant Owners, or any of them, of a portion or all of its interest
in the Coal Contract.

     10.3 Western’s interest in this Agreement may be transferred or assigned to a third party only
in conjunction with the assignment or transfer to said third party of (a) Western’s entire
Ownership and operating interests in the Conveyor, and (b) Western’s entire interest in the Coal
Contract. Such an assignment or transfer may be made by Western only after Western has first
offered to transfer its interest in this Agreement to the Plant Owners for the amount of and on
terms not less advantageous than those of a bona fide offer from a buyer able and willing to
purchase Western’s interest. Western shall advise Plant Owners, in writing, of the name of the
proposed buyer, the proposed purchase price, the terms of sale and of such other information as may
be necessary in order for Plant Owners to properly evaluate the offer. Plant Owners shall have
three (3) months after the written notice from Western to elect to exercise the right to purchase.
If Plant Owners elect not to purchase Western’s Ownership interests in the coal Conveyor system,
then Western may assign or transfer its interest in this Agreement to the

-11-

 

person named in the notice to Plant Owners (“third party transferee”), which assignment or
transfer shall be made subject to the following conditions:

          (a) The assignment or transfer to the third party transferee must be completed within one (1)
year from the date of the notice to Plant Owners.

          (b) As a condition of the assignment or transfer, the third party, transferee must agree to be
bound by each and every term and condition of this Agreement, including the restriction on
transfers and assignments.

          (c) The transfer or assignment to the third party transferee shall not directly or indirectly
result in an increase in any of the costs included in, or taken into account in the determination
of, the Base Price. Without limiting the generality of the foregoing, the following shall apply:
If the third party transferee’s costs are higher than Western’s costs for the same items, then the
third party transferee shall absorb the difference in costs and any adjustment thereafter in the
Base Price shall be based upon any subsequent changes in third party transferee’s costs; the third
party transferee shall maintain the same depreciation basis and rates with respect to any
transferred property as that maintained by Western; and any increase in ad valorem or other taxes
resulting or based upon the transfer shall be absorbed by the third party transferee and thereafter
any adjustments in the Base Price with respect to ad valorem taxes on transferred property shall be
based upon subsequent changes in third party transferee’s costs.

     (d) Prior to the transfer, the third party transferee shall furnish evidence satisfactory to
Plant Owners of its financial capability to perform under this contract and shall furnish, if
requested by Plant Owners, a bond in form satisfactory to Plant Owners guaranteeing to Plant Owners
that the third party transferee will perform each of the terms and conditions of this Agreement and
will meet all of its financial obligations as required.

11 — ARBITRATION

     Any controversies between the parties hereto arising out of or relating to this Agreement or
the breach thereof which cannot be resolved by negotiations within thirty (30) days after notice by
either party to the other shall be submitted to an Arbitrator, competent and experienced in coal
industry accounting and operations. If the parties cannot mutually agree upon such Arbitrator, then
upon petition of either party, such Arbitrator shall be appointed by the senior United States Judge
for the District of Montana. The arbitration shall be conducted under the rules of the American
Arbitration Association. The Arbitrator shall render his decision in writing not later than thirty
(30) days after the matter has been submitted ‘to him, and such decision shall be conclusive and
binding upon the Plant Owners and Western. Western and Plant Owners shall each bear one-half the
cost of the Arbitrator.

12 — LAW GOVERNING CONSTRUCTION OF CONTRACT

     This contract shall be subject to and governed by the law of the State of Montana,
irrespective of the fact that one or more of the parties is now or may become a resident of a
different state.

-12-

 

13 — NOTICES AND REPORTS

     All notices or reports provided for under this Agreement shall be in writing and shall be sent
by United States mail, postage prepaid, and properly addressed:

	 	(a)	 	If to Plant Owners,
	 
	 	 	 	Puget Sound Power & Light Company/PCCC

Puget Power Building

Bellevue, Washington 98009
	 
	 	 	 	The Washington Water Power Company

1411 East Mission

P. O. Box 3727

Spokane, Washington 99220
	 
	 	 	 	Portland General Electric Company

121 S. W. Salmon

Portland, Oregon 97204
	 
	 	 	 	Pacific Power & Light Company

Public Service Building

920 S. W. Sixth Avenue

Portland, Oregon 97204
	 
	 	 	 	The Montana Power Company

40 East Broadway

Butte, Montana 59701
	 
	 	 	 	Basin Electric Power Cooperative

1717 East Interstate Avenue

Bismarck, North Dakota 58501
	 
	 	(b)	 	If to Western,
	 
	 	 	 	Western Energy Company

107 East Granite Street

Butte, Montana 59701

14 — RECORDS TO BE KEPT

     14.1 Western will keep accurate and satisfactory records and books of account showing all
costs, payments, price revisions, adjustments, credits, debits and all other data required for the
purposes of this Agreement. Whenever the Base Price is revised in accordance with the provisions
of Section 6, and at any other time upon fifteen (15) days notice from Plant Owners, or any of
them, Western shall furnish or cause to be furnished to such Plant Owners a detailed statement
showing Western’s Base Price as revised and the basis for the revisions to be

-13-

 

made. If any such statement discloses that any error has occurred and that, as a result
thereof, an overpayment or an underpayment has been made, the amount thereof plus interest, at the
rate of 1 1/2% per month or the highest lawful rate, whichever is lower, shall promptly be paid to
the party to whom it is owed by the other party.

     14.2 Western and Plant Owners shall have the right at all reasonable times to examine the
records kept by the other concerning this Agreement, including weights of the coal transported
hereunder.

15 — AGENT OF PLANT OWNERS

     The parties hereto acknowledge that Plant Owners are a party to an agreement entitled
Ownership and Operation Agreement Colstrip Units #3 and #4, dated May 6, 1981 which agreement names
The Montana Power Company as the operator of the Generating Plant. Western herein, therefore,
agrees to recognize Montana as the operator of the Generating Plant and as the agent of Plant
Owners thereunder for purposes of scheduling, transportation and deliveries of coal and the giving
of notices herein mentioned respecting all coal transported under this Agreement until such time as
Plant Owners, in writing, designate a new or different agent. Nothing herein shall prevent any
Plant Owner from acting on its own behalf respecting coal transportation hereunder providing it
first notifies, in writing, the other parties of its intention to do so.

16 — PERPETUITIES

     If the duration of any term or condition of this Agreement shall be subject to the rule
against perpetuities or a similar or related rule, then the effectiveness of such term or condition
shall not extend beyond (a) the maximum period of time permitted under such rule, or (b) the
specific applicable period of time expressed in the Agreement, whichever is shorter. For purposes
of applying the rule against perpetuities or a similar or related rule the measuring lives in being
shall be those of the officers of Plant Owners, respectively, listed by name on the Schedule of
Officers of the annual reports of the respective Plant Owners, FERC Form 1, filed with the Federal
Energy Regulatory Commission for the year ended on December 31, 1980, together with all those
officers’ children that are living on the date of execution of this Agreement. As used in this
paragraph the word “children” shall have its primary and generally accepted meaning of descendants
of the first degree.

17 — COMPLIANCE

     Western shall comply with all applicable laws and regulations in its performance of this
contract.

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     IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed in
several counterparts, by their respective corporate officers thereunto duly authorized, as of the
day and year first above written.

	 	 	 	 	 	 	 
	“PLANT OWNERS”	 	“WESTERN”
	 
	 	 	 	 	 	 
	PUGET SOUND POWER & LIGHT COMPANY	 	WESTERN ENERGY COMPANY
	 
	 	 	 	 	 	 
	By:

	 	/s/ D. H. Knight
	 	By:
	 	/s/ Martin A. White
	 

	 	 
	 	 	 	 
	 
	 	 	 	 	 	 
	ATTEST:	 	ATTEST:
	 
	 	 	 	 	 	 
	By:

	 	/s/ W. E. Watson
	 	By:
	 	/s/ T. O. McElwain
	 

	 	 
	 	 	 	 
	 

	 	(SEAL)
	 	 	 	(SEAL)
	 
	 	 	 	 	 	 
	PUGET COLSTRIP CONSTRUCTION COMPANY	 	 	 	 
	 
	 	 	 	 	 	 
	By:

	 	/s/ D. H. Knight	 	 	 	 
	 

	 	 	 	 	 	 
	 
	 	 	 	 	 	 
	ATTEST:	 	 	 	 
	 
	 	 	 	 	 	 
	By:

	 	/s/ W. E. Watson	 	 	 	 
	 

	 	 	 	 	 	 
	 

	 	(SEAL)	 	 	 	 
	 
	 	 	 	 	 	 
	WASHINGTON WATER POWER COMPANY	 	 	 	 
	 
	 	 	 	 	 	 
	By:

	 	/s/ H. W. Harding	 	 	 	 
	 

	 	 	 	 	 	 
	 
	 	 	 	 	 	 
	ATTEST:	 	 	 	 
	 
	 	 	 	 	 	 
	By:

	 	/s/ R. L. Strenge	 	 	 	 
	 

	 	 	 	 	 	 
	 

	 	(SEAL)	 	 	 	 

-15-

 

[Map Graphic Intentionally Omitted]

-16-

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