Document:

Exhibit 4.4

 

Form of First Mortgage Bond, Series 2014E-2, due 2044

 

THIS BOND IS A GLOBAL BOND AS DESCRIBED IN THE THIRTY-FOURTH SUPPLEMENT HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF THE DEPOSITORY TRUST COMPANY, A NEW YORK CORPORATION (“DTC” OR THE “DEPOSITARY”), OR A NOMINEE THEREOF.

 

UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY, A NEW YORK CORPORATION (“DTC”), NEW YORK, NEW YORK, TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR IN SUCH OTHER NAME AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT IS MADE TO CEDE & CO. OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

 

TRANSFERS OF THIS SECURITY SHALL BE LIMITED TO TRANSFERS IN WHOLE, BUT NOT IN PART, TO DTC, TO NOMINEES OF DTC OR TO A SUCCESSOR THEREOF OR SUCH SUCCESSOR’S NOMINEE, AND TRANSFERS OF PORTIONS OF THIS GLOBAL SECURITY SHALL BE LIMITED TO TRANSFERS MADE IN ACCORDANCE WITH THE RESTRICTIONS SET FORTH IN THE MASTER INDENTURE REFERRED TO ON THE REVERSE HEREOF.

 

 

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

4.70% FIRST MORTGAGE BONDS, SERIES 2014E- 2, DUE 2044

 

	
$250,000,000
    	
[                ],   2015
    
	
No.
    	
CUSIP:   [                ]
    

 

FOR VALUE RECEIVED, TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC., a cooperative corporation duly organized under the law of the State of Colorado (the “Company”), hereby promises to pay to CEDE & CO., or registered assigns, at the principal corporate trust office of the Trustee, in Minneapolis, Minnesota, the principal sum of Two Hundred Fifty Million Dollars (or such lesser amount as shall equal the aggregate unpaid principal amount of this Bond), in lawful money of the United States of America and in immediately available funds, on November 1, 2044, and to pay interest, in like money and funds (computed on the basis of a 360-day year of twelve 30-day months) on the unpaid principal amount of this Bond for the period commencing on the date hereof until this Bond shall be paid in full, at a rate equal to four and 70/100 percent (4.70%) per annum, payable semi-annually on each May 1 and November 1 of each year, commencing May 1, 2015 (each an “Interest Payment Date”) to the person in whose name this Bond is registered at the close of business on the regular record date for such interest, which shall be April 15 or October 15, respectively (each a “Regular Record Date”) (whether or not a Business Day), as the case may be, immediately preceding each such interest payment date, and at final maturity.

 

This Bond is one of an authorized tranche of an authorized series of First Mortgage Bonds, Series 2014E (collectively, the “Bonds”) referred to as the 4.70% First Mortgage Bonds, Series 2014E- 2, due 2044 (the “Tranche 2 Bonds”). The Bonds consist of two tranches — the 3.70% First Mortgage Bonds, Series 2014E-1, due 2024 in the initial aggregate principal amount of $250,000,000 and the Tranche 2 Bonds in the initial aggregate principal amount of $250,000,000. The Bonds were issued pursuant to and subject to the Master First Mortgage Indenture, Deed of Trust and Security Agreement, Amended, Restated and Effective as of December 15, 1999, between the Company and Wells Fargo Bank, National Association, a national banking association (as successor through consolidation to Wells Fargo Bank West, National Association), as Trustee, as previously supplemented and amended by thirty-two supplemental indentures and as further supplemented and amended by the Supplemental Master Mortgage Indenture No. 34, effective as of October 30, 2014 (the “Thirty-fourth Supplement”) (as so supplemented and amended and as may be further supplemented or amended according to its terms, the “Master Indenture”). Terms used but not defined in this Bond have the respective meanings assigned to them in the Master Indenture.

 

 

	
 
    	
TRI-STATE   GENERATION AND TRANSMISSION
   ASSOCIATION, INC.
    
	
 
    	
 
    
	
 
    	
 
    
	
 
    	
By:
    	
 
    
	
 
    	
 
    	
Name:
    
	
 
    	
 
    	
Its
    

 

	
(SEAL)
    	
 
    
	
 
    	
 
    
	
Attest:
    	
 
    
	
 
    	
 
    
	
 
    	
 
    
	
 
    	
 
    
	
Secretary
    	
 
    

 

CERTIFICATE OF AUTHENTICATION

Series 2014E Secured Obligations

 

(1)                                 This instrument is a Secured Obligation under the terms of that certain Master First Mortgage Indenture, Deed of Trust and Security Agreement, as amended, restated and dated effective as of December 15, 1999, as amended (the “Master Indenture”) and is secured thereunder on a parity with other Secured Obligations.

 

(2)                                 In the event of the occurrence and continuance of an Event of Default under the Master Indenture, the Trustee shall enforce the remedies set forth under the Master Indenture for the benefit of all of the Holders of Secured Obligations.

 

	
 
    	
WELLS   FARGO BANK, NATIONAL ASSOCIATION, 
   AS TRUSTEE
    
	
 
    	
 
    
	
 
    	
 
    
	
 
    	
By:
    	
 
    
	
 
    	
 
    	
Authorized   Signatory
    

 

Signature Page of First Mortgage Bonds, Series 2014E

Series 2014E-2, due 2044

 

 

REVERSE OF 4.70% FIRST MORTGAGE BONDS, SERIES 2014E-2, DUE 2044

 

This Bond is one of the duly authorized issue of debentures, notes, bonds or other evidences of indebtedness of the Company, of the series herein specified, all issued or to be issued pursuant to and subject to the Master Indenture.

 

Except as otherwise provided herein, this Bond may be redeemed in accordance with the procedures set forth in the Master Indenture on not less than 30 nor more than 60 days’ notice given as provided in the Master Indenture, as a whole or in part, at any time at the option of the Company, at the “Make-Whole Price” equal to the greater of (i) 100% of the principal amount of this Bond being redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest thereon (not including any portion of such payments of interest accrued as of the redemption date) discounted to the redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at a rate equal to the sum of (a) the yield to maturity, determined on the third Business Day prior to the redemption date, of the U.S. Treasury security having a life equal to the remaining average life of the maturity of this Bond and trading in the secondary market at the price closest to par, and (b) 25 basis points; plus, in either case, accrued and unpaid interest on the principal amount of this Bond being redeemed to but excluding the redemption date.

 

If there is no U.S. Treasury security having a life equal to the remaining average life of this Bond, the discount rate will be calculated using a yield to maturity determined on a straight- line basis (rounding to the nearest calendar month, if necessary) from the average yield to maturity, determined on the third Business Day prior to the redemption date, of two U.S. Treasury securities having lives most closely corresponding to the remaining average life of this Bond and trading in the secondary market at the price closest to par.

 

If less than all the Tranche 2 Bonds are to be redeemed, the Trustee will select the Tranche 2 Bonds to be redeemed by such method as the Trustee deems fair and appropriate. The Trustee may select for redemption Tranche 2 Bonds in a minimum denomination of $2,000 and integral multiples of $1,000 in excess thereof. So long as Cede & Co., as nominee for DTC, is the sole registered Holder of the Tranche 2 Bonds, partial redemptions will be administered in accordance with DTC procedures, which may require such partial redemptions to be determined by lot. In the event of a partial redemption of the Tranche 2 Bonds, the Company will issue new Tranche 2 Bonds for the unredeemed portion in the name of each Holder of the partially redeemed Bonds.

 

On or after May 1, 2044 (which is the date that is six months prior to the maturity date of the Tranche 2 Bonds), this Bond will be redeemable upon not less than 30 nor more than 60 days’ prior notice given to the Holder of this Bond, at a redemption price equal to 100 percent of the principal amount of this Bond plus accrued and unpaid interest to the date of redemption.

 

If at the time of mailing of notice for the optional redemption the Company has not deposited with the Trustee moneys sufficient to redeem all of the Tranche 2 Bonds called for redemption, the notice of optional redemption given by the Trustee will so state and will further state that the redemption of the Tranche 2 Bonds is conditional upon the Company providing, or causing to be provided, to the Trustee, by 2:00 p.m. New York City time, on the redemption date, funds sufficient to effect the redemption, and the Tranche 2 Bonds will not be redeemed unless such funds are deposited. The failure of the Trustee to have sufficient funds to effect the redemption will not constitute a payment or other default by the Company under the Master Indenture and the Company will not be liable to any Holder of those Tranche 2 Bonds as a result

 

 

of the failed redemption. If the Trustee has sufficient designated funds on deposit to effect a redemption at the time the Company or, at the Company’s request, the Secured Obligation Registrar, gives notice of the redemption, then the Company is obligated to redeem the Tranche 2 Bonds as provided in that notice.

 

Unless the Company defaults in payment of the redemption price and accrued interest, if any, the portion of Tranche 2 Bonds called for redemption will no longer accrue interest on and after the redemption date.

 

The Master Indenture contains provisions for defeasance of the entire indebtedness of this Bond upon compliance by the Company with certain conditions set forth in the Master Indenture.

 

If an Event of Default with respect to this Bond shall occur and be continuing, the unpaid principal of this Bond may be declared due and payable in the manner and with the effect provided in the Master Indenture.

 

The Master Indenture may be amended from time to time pursuant to Article IX of the Master Indenture. Pursuant to the Master Indenture, certain amendments may be effected without the consent of the Holders of any Secured Obligations, including the Tranche 2 Bonds, or with only the consent of the Holders of a majority in aggregate principal amount of the Secured Obligations Outstanding on the Special Record Date established by the Trustee for determining such consents.

 

As provided in the Master Indenture and subject to certain limitations therein set forth, the transfer of this Bond is registrable in the Secured Obligation Register, upon surrender of this Bond for registration of transfer at the office or agency of the Trustee in any place where the principal of (and premium, if any) and interest, if any, on this Bond is payable. When surrendered for transfer, this Bond shall (if so required by the Company or the Trustee or any transfer agent) be duly endorsed or accompanied by a written instrument of transfer in form satisfactory to the Company and the Secured Obligation Registrar or any transfer agent duly executed by the Holder hereof or his attorney duly authorized in writing, and thereupon one or more Bonds of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

 

This Bond is a Secured Obligation under the terms of the Master Indenture and is secured thereunder on a parity with other Secured Obligations. In the event of the occurrence and continuance of an Event of Default under the Master Indenture, the Trustee shall enforce the remedies set forth under the Master Indenture for the benefit of all of the Holders of Secured Obligations in the manner specified in the Master Indenture.

 

This Bond is not subject to any sinking fund.

 

This Bond is entitled to the benefit of the lien under the Master Indenture.

 

Each Holder, by accepting a Bond, agrees to be bound by all the terms and provisions of the Master Indenture, as the same may be amended from time to time in accordance with its terms.

 

Unless the certificate of authentication hereon has been executed by the Trustee or an authenticating agent under the Master Indenture by manual signature, this Bond shall not be entitled to any benefit under the Master Indenture or be valid or obligatory for any purpose.

 

This Bond shall be governed by, and construed in accordance with, the law of the State of New York.Exhibit 10.1

 

AMENDED AND SUBSTITUTED

 

WHOLESALE POWER CONTRACT

 

by and between

 

BASIN ELECTRIC POWER COOPERATIVE

 

and

 

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

THIS AGREEMENT, Made as of January 16, 1975, between Basin Electric Power Cooperative (hereinafter called the “Seller”), a corporation organized and existing under the laws of the State of North Dakota, and Tri-State Generation and Transmission Association, Inc. (hereinafter called the “Member”), a corporation organized and existing under the laws of the State of Colorado:

 

WITNESSETH:

 

WHEREAS, the Seller has constructed an electric generating plant and transmission system, and may construct additional generating capacity or purchase or otherwise obtain electric power and energy for the purpose, among others, of supplying electric power and energy to borrowers from the Rural Electrification Administration which are or may become members of the Seller; and

 

WHEREAS, the Seller has contracted for the introduction of the power and energy produced by such electric generating plant into the transmission system of the Bureau of Reclamation for delivery to its members through facilities of the Bureau of Reclamation including both transmission lines and substation equipment; and

 

 

WHEREAS, the Seller, along with other electric cooperatives, has entered into a contract with the Bureau of Reclamation to establish a “Joint Transmission System” including specifically described facilities and contemplated additions to said Joint Transmission System under certain conditions, over which said Joint Transmission System Seller may deliver to Member electric service; and

 

WHEREAS, the Seller may construct or contract for the use of delivery facilities to make delivery of power and energy to its Members in addition to delivery facilities of the Joint Transmission System, and contemplates construction or contract for the use of specific facilities for the specific purpose of delivering power and energy to Member for resale to its members in Colorado and Wyoming; and

 

WHEREAS, the Member has heretofore entered into a Wholesale Power Contract with Seller dated August 12, 1964, Supplement No. 1 thereto dated March 19, 1965, and an Amendment thereto dated November 16, 1967 (hereinafter collectively called the “Power Contract”), and the parties hereto desire to further amend said Power Contract on the terms and conditions set forth herein, and to incorporate the original contract and all amendments in one amended and substituted wholesale power contract;

 

NOW, THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereto agree as follows:

 

“1.                                     General. The Seller shall sell and deliver to the Member and the Member shall purchase and receive from the Seller the electric power and energy which the Member shall require in addition to power and energy available to the Member from the other

 

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power sources listed below, to the extent that the Seller shall have such power and energy and facilities available, but not to exceed the following:

 

1.1                               The maximum demand of the member supplied by the Seller for delivery to Member’s Nebraska electric service requirements in the month when the simultaneous maximum demands of the Member’s Nebraska requirements for electric service and all other Member cooperatives supplied by the Seller equal in the aggregate the firm delivery capability of the following resources of the Seller:

 

a.                              Leland Olds Generating Station, Units Numbers 1 and 2;

 

b.                              280 MW peaking capacity purchased from the Bureau of Reclamation; and

 

c.                               Seller’s portion of the capability of the Missouri Basin Joint Power Project, to be constructed by the Seller and other bulk electric suppliers, presently contemplated to be completed in 1986. The exact total capacity and location of units of the Missouri Basin Joint Power Project has not been determined at the time of execution of this Amendment.

 

shall be the maximum demand for electric power which Seller shall be obligated to supply to the Member for Nebraska loads. Seller shall notify Member the total resources available to Seller as soon as Item c above has been determined. Upon the determination of the maximum demand for electric power which Seller shall be obligated to supply to the Member, Seller shall advise the Member of such determination, and such number shall be the maximum demand which Seller shall be  obligated to deliver to the Member for Nebraska loads for the remainder of the term of this contract.

 

1.2                               100,000 KW delivered at 230 KV at the Western side of an AC/DC/AC tie to be constructed and interconnected with the Joint Tranmission System, to serve Colorado and Wyoming loads of the Member:

 

provided, however:

 

a.                              The power and energy purchased hereunder shall be furnished in accordance with the normal load pattern of the Member’s system;

 

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b.                              Seller’s obligation to furnish and the Member’s obligation to receive and pay for electric power and energy hereunder shall commence upon completion of the generation and transmission facilities necessary for service hereunder and upon the availability to the Seller of necessary transmission and related facilities, including those of the Bureau of Reclamation;

 

c.                               The Member shall have the right during the term of this Agreement to continue to obtain power and energy from the power sources and in the amounts listed below:

 

	
Bureau   of Reclamation
    	
 
    	
contract rate of del.
    	
 
    	
KW
    
	
Basin   Electric Power Coop.
    	
 
    	
100,000
    	
 
    	
KW
    
	
Member’s   Generating Plant
    	
 
    	
 
    	
 
    	
KW
    
	
Other
    	
 
    	
 
    	
 
    	
KW
    

 

provided, however, that if the Seller at any time and from time to time is unable to sell on a firm power rate basis the entire capacity of the Seller’s generating unit, and there is in effect an agreement between the Seller and the United States (acting through the Bureau of Reclamation) permitting such action, the Member shall reduce its purchases from the Bureau of Reclamation to the extent requested by the Seller and shall increase its purchases from the Seller in the amount of the requested reduction of purchases from the Bureau of Reclamation. The amount of reduction of Bureau of Reclamation power purchases which the Member shall be requested to make shall either

 

i.                                          bear the same ratio to the aggregate of the reductions which all members shall be requested to make as the contract rate of delivery of the Member under its contract with the Bureau of Reclamation bears to the aggregate of the contract rates of delivery to all Members under their contracts with the Bureau of Reclamation; or

 

ii.                                       be such other amount as the Seller and the Member may agree upon in order to minimize the loss in wheeling payments from, and billing penalty payments to, the Bureau of Reclamation under all the Members’ contracts with the Bureau of Reclamation. To the extent that the reduction of power purchases from the Bureau of Reclamation by the Member pursuant to such request of the Seller results in:

 

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i.                                  the loss of wheeling payments which otherwise would have been made to the Member by the Bureau of Reclamation, or

 

ii.                                       in the Member’s becoming liable for billing penalty payments under its power contract with the Bureau of Reclamation which it would not have otherwise incurred, the amounts thereof shall be determined and the effects spread equitably among all the Members by means of a surcharge in the Rate Schedule.

 

d.                              In addition to the supply under the preceding paragraph (c), the Member shall have the right to continue to purchase power and energy under the following contract(s) during the remainder of the term thereof and shall terminate such contract(s) as soon as it may legally do so if the Seller shall, with the approval or at the direction of the Administrator of the Rural Electrification Administration (hereinafter called the “Administrator”), so request:

.

 

2.                                      Electric Characteristics and DeliveryPoint(s). Electric power and energy to be furnished hereunder shall be alternating current, three phase, sixty cycle. The Seller shall deliver such electric power and energy into the transmission system of the Bureau of Reclamation, and the Member shall receive such power and energy at the point(s) of delivery on the transmission system of the Bureau or the joint transmission system contemplated to be established by a Pooling Agreement between the Seller, Bureau and others, as shall be scheduled by the Member, and such other point or points as may be agreed upon by the Seller and the Member.

 

3.                                      Substation. Delivery of electric power and energy shall be through the necessary substation equipment at the point(s) of connection with the transmission system of the Bureau of Reclamation or the joint system. The Member shall own and maintain switching and protective equipment which may be reasonably necessary to enable the Member to take and use the electric power and energy hereunder. Meters and metering equipment shall be furnished, maintained and read by the Bureau of Reclamation and shall be located at the point of delivery on the low voltage side of such transforming equipment.

 

4.                                      Rate.                           (a)                         The Member shall pay the Seller for all electric power and energy furnished hereunder as the rates and on the terms and conditions set forth in Rate Schedule “A”, attached hereto and made a part hereof.

 

(b)                         The Board of Directors of the Seller at such intervals as it shall deem appropriate, but in any event not less frequently than once in each calendar year, shall review the rate

 

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for electric power and energy furnished hereunder and under similar agreements with other Members and, if necessary, shall revise such rate so that it shall produce revenues which shall be sufficient, but only sufficient, with the revenues of the Seller from all other sources, to meet the cost of the operation and maintenance (including, without limitation, replacements, insurance, taxes and administrative and general overhead expenses) of the generating plant, transmission system and related facilities of the Seller, the cost of any power and energy purchased for resale hereunder by the Seller, the cost of transmission service, make payments on account of principal of and interest on all indebtedness of the Seller, and to provide for the establishment and maintenance of reasonable reserves. The Seller shall cause a notice in writing to be given to the Member and other Members of the Seller and the Administrator which shall set out all the proposed revisions of the rate with the effective date thereof, which shall be not less than thirty (30) nor more than forty-five (45) days after the date of the notice, and shall set forth the basis upon which the rate is proposed to be adjusted and established. The Member agrees that the rate from time to time established by the Board of Directors of the Seller shall be deemed to be substituted for the rate herein provided and agrees to pay for electric power and energy furnished by the Seller to it hereunder after the effective date any such revisions at such revised rates; provided, however, that no such revision shall be effective unless approved in writing by the Administrator.

 

(c)                          By reason of the construction of the AC/DC/AC tie addition to the Joint Transmission System as contemplated by this Power Contract, for delivery of electric service contemplated in Paragraph 1.2 hereof, Member shall pay for actual demand of electric service delivered at the western side of said AC/DC/AC tie until such demand shall first measure 100,000 KW on a seasonal basis, and thereafter, the Member shall pay monthly for the appropriate kilowatts system load pattern related to a minimum of 100,000 KW of demand in at least one month each season (winter and summer), for the term of this contract. Member shall be responsible for providing and paying for reserves against the outage of the AC/DC/AC tie until the Seller owns generating capacity in excess of 100,000 KW located west (electrically) of the AC/DC/AC tie, at which time the Seller shall become responsible for providing and paying for such reserves.

 

5.                              Meter Readings and Payment of Bills. Appropriate operating procedures shall be established to monthly determine the electric power and energy delivered and to be billed by Seller to the Member. Electric power and energy furnished hereunder shall be paid for at the office of the Seller in Bismarck, North Dakota, monthly within fifteen (15) days after the bill therefor is mailed to the Member. If the Member shall fail to pay any such bill within such fifteen-day period, the Seller may discontinue delivery of electric power and energy hereunder upon fifteen (15) days’ written notice to the Member of its intention so to do.

 

6.                              Meter Testing and Billing Adjustment. All meters shall be tested and calibrated as provided for in the contract between the

 

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Member and the Bureau of Reclamation. The Member shall request a special test of meters delivering power or energy to it under the Member’s contract with the Bureau of Reclamation, upon the request of the Seller. If any special meter test made at the Seller’s request shall disclose that the meters are recording accurately, the Seller shall reimburse the Member for the cost of such test. Meters registering not more than two per cent (2%) above or below normal shall be deemed to be accurate. The readings of any meter which shall have been disclosed by test to be inaccurate shall be corrected for the ninety (90) days previous to such test in accordance with the percentage of inaccuracy found by such test. If any meter shall fail to register for any period, the Member and the Seller shall agree as to the amount of energy furnished during such period and the Seller shall render a bill therefor.

 

7.                                      Notice of Meter Reading or Test. The Member shall notify the Seller in advance of the time of any meter reading or test so that the Seller’s representative may be present at such meter reading or test.

 

8.                                      Right of Access. Duly authorized representatives of either party hereto shall be permitted to enter the premises of the other party hereto at all reasonable times in order to carry out the provisions hereof.

 

9.                                      Continuity of Service. The Seller shall use reasonable diligence to provide a constant and uninterrupted supply of electric power and energy hereunder. If the supply of electric power and energy shall fail or be interrupted, or become defective through an act of God or of the public enemy, or because of accident, failure in the joint transmission system, labor troubles, or any other cause beyond the control of the Seller, the Seller shall not be liable therefor or for damages caused thereby.

 

10.                               Term. This Agreement shall become effective only upon approval in writing by the Administrator and be substituted for th existing wholesale power contract, and all amendments thereto, shall remain in effect until January 1, 2020, and thereafter until terminated by either party’s giving to the other not less than six months’ written notice of its intention to terminate. Subject to the provisions of Article I hereof, service hereunder and the obligation of the Member to pay therefor shall commence upon completion of the facilities necessary to provide service.

 

EXECUTED the day and year first above mentioned.

 

	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE,
    
	
 
    	
 
    	
Seller
    
	
 
    	
 
    	
 
    
	
 
    	
By
    	
/s/Arthur   Jones
    
	
 
    	
 
    	
President
    
				

 

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ATTEST:
    	
 
    
	
 
    	
 
    
	
 
    	
 
    
	
/s/Dennis   Lindberg
    	
 
    
	
 
    	
Secretary
    	
 
    
			

 

 

	
 
    	
TRI-STATE   GENERATION AND
    	
 
    
	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    	
 
    
	
 
    	
 
    	
Member
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
By
    	
/s/Everett   B. Chesney
    	
 
    
	
 
    	
 
    	
President
    	
 
    
	
 
    	
 
    	
 
    	
 
    
					

 

 

	
ATTEST:
    	
 
    
	
 
    	
 
    
	
 
    	
 
    
	
/s/E.A.   Geesen
    	
 
    

 

 

AMENDMENT NO. 1

TO

AMENDED AND SUBSTITUTED

WHOLESALE POWER CONTRACT

BY AND BETWEEN

BASIN ELECTRIC POWER COOPERATIVE

AND

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

THIS AMENDMENT NO. 1, made this 7th day of October , 1987, by and between Basin Electric Power Cooperative, 1717 East Interstate Avenue, Bismarck, North Dakota 58501 (hereinafter called Basin Electric) an electric cooperative corporation organized and existing under the laws of the State of North Dakota, and Tri-State Generation and Transmission Association, Inc., P.O. Box 33695, 12076 Grant Street, Denver, Colorado 80233-0695 (hereinafter called Tri-State), its successors and assigns, a corporation organized and existing under the laws of the State of Colorado; (Basin Electric and Tri-State are collectively referred to herein as Parties).

 

WITNESSETH:

 

WHEREAS, the Parties entered into an Amended and Substituted Wholesale Power Contract dated as of January 16, 1975 (Original Contract); and

 

WHEREAS, Tri-State has entered into a contract for firm electric service, Contract 87-LA0-134, dated April 28, 1987 with the United States Department of Energy, Western Area Power Administration; and

 

 

WHEREAS, the Parties desire to amend the Original Contract to establish the maximum contract rate of delivery for the Nebraska loads of Tri-State furnished by Basin Electric, to incorporate certain changes to facilitate incorporation of Contract No. 87-LA0-134, and to make other mutually beneficial changes to the terms of the Original Contract.

 

NOW, THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereby agree as follows:

 

1.                                      Section 1 is deleted in its entirety and the following is substituted in its place:

 

1.                                      GENERAL

 

A.                 Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric 100,000 kW of capacity and energy for Tri-State loads in Colorado/Wyoming. The capacity and energy shall be furnished in accordance with the normal seasonal load pattern of Tri-State’s Colorado/Wyoming system and shall reflect a 100,000 kW schedule in at least one month of each season (winter and summer). The scheduling procedures and energy loss provisions are provided for in Exhibit I attached hereto.

 

B.                 Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric for its Nebraska loads all electric capacity and energy which Tri-State shall require

 

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up to 405,000 kW of capacity and associated energy in addition to the capacity and energy available to Tri-State from the Western Area Power Administration (WAPA). The amount of WAPA capacity and energy available for use for the Nebraska loads and provisions for supplemental power are set forth in Exhibit II.

 

C.                 The parties recognize that the amount of WAPA power available for Nebraska loads set forth in Exhibit II are based upon the WAPA Contract No. 87-LA0-134 allocation which will expire on the last day of the September billing period in 2004. Prior to the expiration of Contract No. 87-LA0-134 allocation, the parties will negotiate a mutually acceptable amendment to Exhibit II to account for any revision to Contract No. 87-LA0-134. Unless otherwise agreed, the amount of WAPA power deemed available for Tri-State will be apportioned between Nebraska and Colorado/Wyoming as described in Section 3.1 of Exhibit II.

 

2.                                      Section 2 is deleted in its entirety and the following is substituted in its place:

 

2.                                      ELECTRIC CHARACTERISTICS AND BASIN ELECTRIC DELIVERY POINTS

 

Electric capacity and energy to be furnished hereunder shall be alternating current, three phase, 60 hertz. Basin Electric shall deliver such electric capacity and energy and Tri-State will receive such capacity and energy at the Basin Electric Points of Delivery

 

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listed on Exhibit III, and at such other Points of Delivery as may be agreed upon by Basin Electric and Tri-State.

 

3.                                      Section 3 is deleted in its entirety and the following is substituted in its place:

 

3.                                      DELIVERY

 

Delivery of electric capacity and energy shall be through the necessary substation equipment at the Points of Delivery listed in Exhibit III. Tri-State shall own or have contractual rights for transmission, and switching and protective equipment which may be reasonably necessary to enable Tri-State to take and use the electric capacity and energy purchased hereunder. Meters and metering equipment shall be furnished, maintained and read by Tri-State or its agent and shall be located at the Points of Delivery or at other points as mutually agreeable. Tri-State is responsible for all transmission and transformation losses from Basin Electric’s Points of Delivery to the points of metering, as noted in Exhibits I, II and III.

 

4.                                      Section 4 is deleted in its entirety and the following is substituted in its place:

 

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4.                                      RATE

 

A.                 Tri-State shall pay Basin Electric for all electric capacity and energy furnished hereunder at the rates and on the terms and conditions set forth in Exhibits I, II and IV.

 

B.                 The Board of Directors of Basin Electric at such intervals as it shall deem appropriate, but in any event not less frequently than once in each calendar year, shall review the rate for electric capacity and energy furnished hereunder and under similar contracts with other members, and, if necessary, shall revise such rate so that it shall produce revenues which shall be sufficient, but only sufficient, with the revenues of Basin Electric from all other sources, to meet the cost of the operation and maintenance (including, without limitation, replacement, insurance, taxes and administrative and general overhead expenses) of the generating plants, the transmission system and related facilities of Basin Electric, the cost of any capacity and energy purchased for resale hereunder by Basin Electric, the cost of transmission service, lease payments, interest expense and depreciation expense of Basin Electric, and to provide for the establishment and maintenance of reasonable reserves. Basin Electric shall cause a notice in writing to be given to Tri-State and other members of Basin Electric and the Administrator which shall set out all of the proposed revisions of rate with the effective date hereof, which shall not be less than thirty (30) nor more than forty-five (45) days after the date of the

 

5

 

notice, and shall set forth the basis upon which the rate is proposed to be adjusted and established. Tri-State agrees that the rate from time-to-time established by the Board of Directors of Basin Electric shall be deemed to be substituted for the rate herein provided and agrees to pay for electric capacity and energy furnished by Basin Electric to it hereunder after the effective date of any such revision at such revised rates; provided, however, that no such revision shall be effective unless approved in writing by the Administrator.

 

C.                 Tri-State shall be deemed eligible to participate in any or all of Basin Electric’s policies for its Nebraska loads which apply to all members who have all requirements contracts so long as Tri-State’s total capacity requirements for its Nebraska loads in excess of those supplied by the WAPA allocation set forth in Exhibit II do not exceed those amounts set forth in Section 1.b above. Any Delivery Point Policy or Delivery Point Policy payment due Tri-State shall be calculated using revenue received from Tri-State’s Nebraska loads and shall be effective with the effective date of this Amendment.

 

5.                                      A new paragraph 11 is added and will read as follows:

 

11.                               EXHIBITS

 

Exhibits I, II and III, attached hereto and made a part hereof, set forth provisions and conditions which may change from time to time.

 

6

 

The parties agree that these exhibits shall remain in effect until superseded by a subsequent exhibit executed by the parties. The parties acknowledge that Exhibit IV is Basin Electric’s Schedule A which is revised from time to time. The parties agree that each revision of Rate Schedule A will be substituted for and supersede the Exhibit IV attached to this Agreement.

 

6.                                      TERM

 

This Amendment shall become effective on the first day of the first billing period after the approval in writing by the Administrator and shall remain in effect until January 1, 2020, and thereafter until terminated by either party’s giving to the other not less than five (5) years written notice of its intention to terminate.

 

7

 

IN WITNESS WHEREOF, Tri-State and Basin Electric have caused this Amendment No. 1 to Amended and Substituted Wholesale Power Contract to be duly executed the year first written above.

 

Executed as of the day and year first above written.

 

	
 
    	
 
    	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
By:   
    	
/s/Quentin   Louden
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Title:   
    	
President
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
ATTEST:
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
By:   
    	
J.   William Keller
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
Title:   
    	
Secretary
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
TRI-STATE   GENERATION AND
    
	
 
    	
 
    	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
By:   
    	
/s/H.J.   Thompson
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Title:   
    	
President   
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
Attest:
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
By:   
    	
/s/William   W. Dallas
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
Title:   
    	
Secretary
    	
 
    	
 
    	
 
    

 

8

 

	
 
    	
Exhibit I
    
	
 
    	
 
    
	
 
    	
Amendment   No. 1
    
	
 
    	
to   Amended and Substituted
    
	
 
    	
Wholesale   Power Contract by
    
	
 
    	
and   Between Basin Electric
    
	
 
    	
Power   Cooperative and Tri-State
    
	
 
    	
Generation   and Transmission
    
	
 
    	
Association, Inc.
    

 

COLORADO-WYOMING DELIVERIES

 

This Exhibit I to Amendment No. 1 of the Amended and Substituted Wholesale Power Contract by and between Basin Electric Power Cooperative and Tri-State Generation and Transmission Association, Inc., shall become effective on the effective date of the Amendment No. 1 and shall remain in effect until superseded by a new Exhibit I or terminated upon the expiration of the Contract. (Amendment No. 1 and the Amended and Substituted Wholesale Power Contract are collectively referred to as the Contract).

 

1.              Written Scheduling, Accounting and Billing Procedures for Colorado-Wyoming Deliveries under Section 1.a. of the Contract shall be developed and agreed upon by representatives of Tri-State and Basin Electric. The Scheduling, Accounting and Billing Procedures are intended to implement the terms of the Contact but not to modify or amend it.

 

2.              Tri-State shall prepare and submit two monthly schedules to Basin Electric and its agents for capacity and energy deliveries to Colorado-Wyoming under the Contract. These schedules shall be for loads located electrically west and electrically east of the east-west electrical

 

1

 

separation and shall generally conform to the normal load pattern of the loads being served. The sum of the schedules shall equal the amounts established in Section 1.a. of the Contract.

 

3.              Basin Electric shall deliver capacity and energy to the interconnected system at the Points of Delivery listed in Exhibit III.

 

4.              Tri-State shall be responsible for all energy losses from Basin Electric’s east-side resources to Basin Electric’s east-side Points of Delivery. Tri-State shall purchase the energy for said losses at Basin Electric’s Laramie River Station production cost plus one and one half mills per kilowatt-hour ($0.0015).

 

5.              Tri-State shall bear the responsibility and costs associated with the transmission of capacity and energy beyond Basin Electric’s Points of Delivery. This shall include, but not be limited to, wheeling, losses and control power charges.

 

2

 

IN WITNESS WHEREOF, Tri-State and Basin Electric have caused this Exhibit I to be duly executed this 7th day of October, 1987.

 

 

	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE
    
	
(SEAL)
    	
 
    
	
 
    	
 
    
	
 
    	
By:
    	
/s/Quentin   Louden
    
	
 
    	
 
    
	
 
    	
Title:   President
    
	
 
    	
 
    
	
ATTEST:
    	
 
    
	
 
    	
 
    
	
By:
    	
J.   William Keller
    	
 
    
	
 
    	
 
    
	
Title:   Secretary
    	
 
    
				

 

	
 
    	
TRI-STATE   GENERATION AND
    
	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    
	
(SEAL)
    	
 
    
	
 
    	
 
    
	
 
    	
By:
    	
/s/H.J.   Thompson
    
	
 
    	
 
    
	
 
    	
Title:   President
    
	
 
    	
 
    
	
Attest:
    	
 
    
	
 
    	
 
    
	
By:
    	
/s/William   W. Dallas
    	
 
    
	
 
    	
 
    
	
Title:   Secretary
    	
 
    
				

 

3

 

	
 
    	
Exhibit II
    
	
 
    	
 
    
	
 
    	
Amendment   No. 1
    
	
 
    	
to   Amended and Substituted
    
	
 
    	
Wholesale   Power Contract by
    
	
 
    	
and   between Basin Electric
    
	
 
    	
Power   Cooperative and Tri-State
    
	
 
    	
Generation   and Transmission
    
	
 
    	
Association, Inc.
    

 

This Exhibit II (revised as of July 1, 1989) to Amendment No. 1 of the Amended and Substituted Wholesale Power Contract by and between Basin Electric Power Cooperative and Tri-State Generation and Transmission Association, Inc., shall supersede and replace the original Exhibit II and shall become effective upon approval by the Administrator of the Rural Electrification Administration and shall remain in effect until superseded by a new Exhibit II or terminated upon the expiration of the Contract. (Amendment No. 1 and the Amended and Substituted Wholesale Power Contract are collectively referred to as the Contract).

 

NEBRASKA DELIVERIES

 

1.              SCHEDULING, ACCOUNTING AND BILLING PROCEDURES

 

Written Scheduling, Accounting and Billing Procedures for Nebraska Deliveries under Section 1.b. of the contract shall be developed and agreed upon by the representatives of Tri-State and Basin Electric. The Scheduling, Accounting and Billing Procedures are intended to implement the terms of the Contract but not to modify or amend it.

 

1

 

2.              PICK-SLOAN MISSOURI BASIN PROJECT - WESTERN DIVISION DELIVERIES UNDER CONTRACT NO. 7-07-70-PO190 (PO-190)

 

Deliveries of Tri-State’s Pick-Sloan Missouri Basin Project-Western Division (P-SMBP-WD) Nebraska Capacity and Energy entitlements under Contract No. PO-190 shall be in accordance with Schedule A as set forth in Exhibit IV. Billing for Basin Electric power deliveries to Nebraska during the term of Contract No. PO-190 shall also be according to Basin Electric’s Schedule A as set forth in Exhibit IV. The P-SMBP-WD Contract Rates of Delivery for Tri-State’s Nebraska loads are 68,300 kilowatts during the Summer Season and 41,770 kilowatts during the Winter Season.

 

3.              PICK-SLOAN MISSOURI BASIN PROJECT - WESTERN DIVISION DELIVERIES UNDER CONTRACT NO. 87-LAO-134 (POST-1989)

 

3.1.              Pro Rata Apportionment of P-SMBP-WD Post-1989 Allocations

 

Under Contract No. 87-LAO-134, Tri-State’s total P-SMBP-WD allocation will be apportioned between Nebraska and Colorado-Wyoming in proportion to the present separate seasonal capacity allocations. The resulting seasonal apportionment percentages for determining the pro rata shares of Tri-State’s Nebraska P-SMBP-WD seasonal capacity and energy allocations under Contract No. 87-LAO-134 are:

 

	
 
    	
Summer Season
    	
 
    	
24.953
    	
%
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
Winter Season
    	
 
    	
18.825
    	
%
    	
 
    

 

2

 

During the term of Contract No. 87-LAO-134, these pro rata apportionment percentages will be applied to all P-SMBP-WD allocations offered by WAPA’s Loveland Area Office (LAO) which Tri-State qualifies to receive; provided, that WAPA places no geographic restrictions on use. Any P-SMBP-WD allocations offered for use solely in Nebraska which Tri-State qualifies to receive will not be subject to apportionment.

 

Applying these Nebraska apportionment percentages to Tri-State’s total Post-1989 P-SMBP-WD seasonal capacity and energy allocations as presently set forth in Contract No. 87-LAO-134, the seasonal capacity and energy Contract Rates of Delivery which Tri-State is entitled to use to serve its Nebraska loads are:

 

	
 
    	
Summer Season
    	
 
    	
86,260   kilowatts
    	
 
    	
125,344   megawatt-hours
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
Winter Season
    	
 
    	
51,944   kilowatts
    	
 
    	
64,424   megawatt-hours
    	
 
    	
 
    

 

Contract No. 87-LAO-134 and WAPA’s Post-1989 Marketing Criteria for P-SMBP-WD power include provisions for adjusting allocations under certain circumstances. If Tri-State’s total seasonal allocations of P-SMBP-WD power are adjusted by WAPA during the term of Contract No. 87-LAO-134, those adjustments will be apportioned between Nebraska and Colorado-Wyoming. The Nebraska apportionment percentages shown above shall be used to determine the pro rata Nebraska share of those adjustments.

 

3

 

3.2.              Monthly Post-1989 P-SMBP-WD Capacity and Energy Entitlements on Resource Pattern

 

WAPA’s Post-1989 Marketing Criteria for P-SMBP-WD power provides that Monthly Capacity and Monthly Energy Entitlements for P-SMBP-WD power deliveries shall be determined on a resource pattern basis. Monthly entitlement percentages for determining Monthly Capacity and Monthly Energy entitlements are set forth in Contract No. 87-LAO-134. Applying the monthly entitlement percentages to the seasonal amounts of Tri-State’s Post-1989 P-SMBP-WD power apportioned to Nebraska, the resultant Monthly Capacity and Monthly Energy entitlements shall be:

 

	
 
    	
Summer Season
    	
 
    	
86,260 kilowatts
    	
 
    	
125,334 megawatt-hours
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
April
    	
 
    	
71,251   kW ( 82.6%)
    	
 
    	
18,300   MWh (14.6%)
    	
 
    
	
 
    	
May
    	
 
    	
66,852   kW ( 77.5%)
    	
 
    	
19,177   MWh (15.3%)
    	
 
    
	
 
    	
June
    	
 
    	
80,222   kW ( 93.0%)
    	
 
    	
22,061   MWh (17.6%)
    	
 
    
	
 
    	
July
    	
 
    	
86,260   kW (100.0%)
    	
 
    	
27,576   MWh (22.0%)
    	
 
    
	
 
    	
August
    	
 
    	
75,823   kW ( 87.9%)
    	
 
    	
22,061   MWh (17.6%)
    	
 
    
	
 
    	
September
    	
 
    	
73,666   kW ( 85.4%)
    	
 
    	
16,169   MWh (12.9%)
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
Winter Season
    	
 
    	
51,944 kilowatts
    	
 
    	
64,424 megawatt-hours
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
October
    	
 
    	
48,100   kW ( 92.6%)
    	
 
    	
10,888   MWh (16.9%)
    	
 
    
	
 
    	
November
    	
 
    	
47,373   kW ( 91.2%)
    	
 
    	
10,888   MWh (16.9%)
    	
 
    
	
 
    	
December
    	
 
    	
51,944   kW (100.0%)
    	
 
    	
11,918   MWh (18.5%)
    	
 
    
	
 
    	
January
    	
 
    	
50,542   kW ( 97.3%)
    	
 
    	
11,596   MWh (18.0%)
    	
 
    
	
 
    	
February
    	
 
    	
46,957   kW ( 90.4%)
    	
 
    	
9,148   MWh (14.2%)
    	
 
    
	
 
    	
March
    	
 
    	
42,594   kW ( 82.0%)
    	
 
    	
9,986   MWh (15.5%)
    	
 
    

 

Contract No. 87-LAO-134 and WAPA’s Post-1989 Marketing Criteria for P-SMBP-WD power include provisions for adjusting allocations under certain circumstances. If Tri-State’s total seasonal or monthly allocations of P-SMBP-WD power are adjusted by WAPA during the Post-1989 contract period, the adjustments will be apportioned between Nebraska and Colorado-Wyoming as described in Section 3.1 above.

 

4

 

Contract No. 87-LAO-134 and WAPA’s Post-1989 Marketing Criteria for P-SMBP-WD power also include provisions for increasing Monthly Energy entitlements if short-term conditions allows. If WAPA increases Tri-State’s Monthly Energy entitlement in any month, the increase will be apportioned between Nebraska and Colorado-Wyoming using the Nebraska apportionment percentages as shown in Section 3.1 above.

 

3.3.              Federal Power Deliveries to Nebraska

 

WAPA’s Post-1989 Firm Electric Service contracts provide for delivery by WAPA of P-SMBP-WD power, to federal delivery points which are electrically east and electrically west. Tri-State shall be able to deliver federal power beyond the federal delivery points; provided, Tri-State will be responsible for all wheeling and losses associated with the delivery of federal power beyond the federal delivery points. These demand and energy losses will be purchased from Basin Electric in accordance with its Rate Schedule A in effect at that time.

 

Tri-State and Basin Electric shall establish scheduling procedures to optimize the integration of Post-1989 P-SMBP-WD allocations to Nebraska per Sections 3.1 and 3.2 with Basin Electric’s supplemental thermal deliveries. For the purpose only of Basin Electric’s power billing to Tri-State, deliveries of P-SMBP-WD power will be deemed to have been made first to those delivery points that have the highest loss factors. This billing assumption shall not affect Basin Electric’s ability to schedule the P-SMBP-WD power to any of the delivery points in order to maximize the integration of the P-SMBP-WD power with Basin Electric’s supplemental deliveries.

 

5

 

3.4                Mt. Elbert Pumped Storage Hydro

 

In addition to Tri-State’s Post-1989 P-SMBP-WD firm capacity and energy allocations, Tri-State will also be entitled to schedule energy to and from a Pumped Storage Energy account. This Pumped Storage Energy account is a direct result of the operational integration of the Fryingpan-Arkansas Project and its Mt. Elbert Pumped Storage units with the P-SMBP-WD hydroelectric system.

 

The seasonal amounts of pumped storage capacity available to Tri-State in connection with its Pumped Storage Energy account will be proportionate to Tri-State’s firm seasonal Contract Rates of Delivery of P-SMBP-WD capacity. The same pro rata apportionment percentages shown in Section 3.1 above will be used to determine the Nebraska pro rata shares of the seasonal pumped storage capacity amounts. Applying these pro rata apportionment percentages, the seasonal amounts of pumped storage capacity available to Tri-State for use in Nebraska shall be:

 

	
 
    	
Summer Season
    	
 
    	
24,184   kilowatts
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
Winter Season
    	
 
    	
16,373   kilowatts
    	
 
    	
 
    

 

The monthly quantities of pumped storage capacity available to Tri-State for use in Nebraska shall be determined by applying the same monthly capacity entitlement percentages used to determine the firm Monthly Capacity entitlements to the seasonal pumped storage capacity amounts shown above. Applying the monthly capacity entitlement percentages to the seasonal pumped storage capacity amounts, the resultant monthly pumped storage capacity amounts available to Tri-State for use in Nebraska shall be:

 

6

 

	
 
    	
Summer Season
    	
 
    	
24,184 kilowatts
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
April
    	
 
    	
19,976   kW ( 82.6%)
    	
 
    	
 
    
	
 
    	
May
    	
 
    	
18,743   kW ( 77.5%)
    	
 
    	
 
    
	
 
    	
June
    	
 
    	
22,491   kW ( 93.0%)
    	
 
    	
 
    
	
 
    	
July
    	
 
    	
24,184   kW (100.0%)
    	
 
    	
 
    
	
 
    	
August
    	
 
    	
21,258   kW ( 87.9%)
    	
 
    	
 
    
	
 
    	
September
    	
 
    	
20,653   kW ( 85.4%)
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
Winter Season
    	
 
    	
16,373 kilowatts
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
 
    	
October
    	
 
    	
15,161   kW ( 92.6%)
    	
 
    	
 
    
	
 
    	
November
    	
 
    	
14,932   kW ( 91.2%)
    	
 
    	
 
    
	
 
    	
December
    	
 
    	
16,373   kW (100.0%)
    	
 
    	
 
    
	
 
    	
January
    	
 
    	
15,931   kW ( 97.3%)
    	
 
    	
 
    
	
 
    	
February
    	
 
    	
14,801   kW ( 90.4%)
    	
 
    	
 
    
	
 
    	
March
    	
 
    	
13,426   kW ( 82.0%)
    	
 
    	
 
    

 

The seasonal and monthly pumped storage capacity amounts available to Tri-State for use in Nebraska as shown above shall remain fixed for the term of Contract No. 87-LAO-134, and will not be affected by any adjustments made by Western to Tri-State’s P-SMBP-WD power allocations. However, if the Mt. Elbert facility and the LAO Pumped Storage option do not operate as assumed in Paragraph 4.4 of this Exhibit, the appropriate adjustments shall be made to the CF factor defined in Paragraph 4.4.

 

3.5.              Use of Federal Capacity and Energy

 

WAPA’s Loveland Area Office may make available other P-SMBP-WD allocations. During the term of Contract No. 87-LAO-134, the pro rata apportionment percentages shown in Section 3.1 above will be applied to all P-SMBP-WD allocations which Tri-State qualifies to receive; provided, that WAPA places no geographic restrictions on use. Any P-SMBP-WD allocations offered for use solely in Nebraska which Tri-State qualifies to receive will not be subject to apportionment.

 

7

 

4.              DETERMINATION OF NEBRASKA CAPACITY AND ENERGY DELIVERED BY BASIN ELECTRIC DURING TERM OF CONTRACT NO. 87-LAO-134

 

4.1.              Basin Electric Deliveries to Nebraska

 

Basin Electric’s deliveries to Tri-State Nebraska will be delivered at the Basin Electric Points of Delivery specified in Exhibit III. For the purpose only of determining the amounts of power delivered to Tri-State in Nebraska by Basin Electric, deliveries will be deemed to have been made at one delivery point, Stegall. Amounts of power deemed to be delivered from Basin Electric to Tri-State at Stegall will be adjusted to properly reflect the losses between the Tri-State metering points and Stegall. Tri-State shall purchase these demand and energy losses from Basin Electric at the Schedule A rate. Basin Electric supplies capacity and bills for capacity supplied on a demand basis. For the purposes of this contract, capacity and demand are deemed to be equivalent terms. The methodology for computing these losses will be set forth in the Scheduling, Accounting and Billing Procedures to be developed pursuant to Section 1 above.

 

4.2.    Basin Electric Supplemental Demand

 

Basin Electric’s Supplemental Demand (Tri-State’s Nebraska supplemental demand requirement supplied by Basin Electric under Section 1.b. of the Contract) in any month shall be determined in accordance with the following formula:

 

BSD = PCML - (MCE * AF) + DLOSS

 

Where:

 

BSD = Basin Electric Supplemental Demand

 

8

 

PCML = Tri-State’s Nebraska Peak Coincident Metered Load as adjusted for losses to the WAPA Points of Delivery where applicable.

MCE = Tri-State’s Nebraska Pro Rata P-SMBP-WD Monthly Capacity Entitlement as determined in Section 3.2.

 

AF = WAPA Diversity Factor

 

DLOSS = Losses to Adjust the Demand Supplied by Basin Electric in accordance with Section 4.1 above from Tri-State’s Points of Delivery to Stegall

 

Tri-State’s Nebraska Peak Coincident Metered Load shall be determined irrespective of the east-west electrical separation. The adjustment to the P-SMBP-WD Monthly Capacity Entitlement for WAPA’s diversity equals losses assumption will be applied only if it is required by WAPA. For the purpose of determining the Basin Electric Supplemental Demand delivered to Tri-State, deliveries will be deemed to have been made at one delivery point, Stegall. The losses to adjust the capacity supplied by Basin Electric to Stegall, the deemed point of delivery, shall be computed according to the loss adjustment figures as established in Exhibit III and to the methodology set forth in the Scheduling, Accounting and Billing Procedures to be developed pursuant to Section 1 above.

 

4.3.     Basin Electric Supplemental Energy

 

Basin Electric Supplemental Energy (Tri-State’s Nebraska supplemental energy requirement supplied by Basin Electric under Section 1.b. of the Contract) in any month shall be determined in accordance with the following formula:

 

BSE = NME - MEE + ELOSS - PSRE

 

Where:

 

BSE = Basin Electric Supplemental Energy

 

NME = Tri-State’s Nebraska Metered Energy as adjusted for losses to the WAPA Points of Delivery where applicable.

 

9

 

MEE = Tri-State’s Nebraska Pro Rata P-SMBP-WD Monthly Energy Entitlement as determined in Section 4.2.

 

ELOSS = Losses to Adjust the Energy Supplied by Basin Electric in accordance with Section 4.1 above from Tri-State’s Points of Delivery to Stegall

 

PSRE = Pumped Storage Replacement Energy Supplied by Basin Electric

 

Tri-State’s Nebraska Metered Energy shall be determined irrespective of the east-west electrical separation. For the purpose of determining the Basin Electric Supplemental Energy delivered to Tri-State, deliveries will be deemed to have been made at one delivery point, Stegall. The losses to adjust the energy supplied by Basin Electric to Stegall, the deemed point of delivery, shall be computed according to the loss adjustment factors as established in Exhibit III and to the methodology set forth in the Scheduling, Accounting and Billing Procedures to be developed pursuant to Section 1 above.

 

4.4.    Pumped Storage Replacement Energy

 

A.     Basin Electric shall supply to Tri-State Pumped Storage Replacement energy equal to the monthly energy capability associated with Tri-State’s monthly pumped storage capacity available for use in Nebraska. Tri-State will purchase this Pumped Storage Replacement energy from Basin Electric in lieu of scheduling Tri-State’s monthly pumped storage capacity available for use in Nebraska.

 

Basin Electric shall have the right to utilize Tri-State’s monthly pumped storage capacity available for use in Nebraska to serve Tri-State’s Nebraska loads, provided, Basin Electric shall be responsible for all costs associated

 

10

 

with the delivery of energy from and the return of energy to the Pumped Storage Energy account.

 

B.     The amount of Pumped Storage Replacement Energy supplied by Basin Electric in any month shall be determined as follows:

 

PSRE = MPSCAP * HOURS * CF

 

Where:

 

PSRE = Pumped Storage Replacement Energy

 

MPSCAP = Monthly Pumped Storage Capacity Available for Use in Nebraska

 

HOURS = Hours in the Billing Period

 

CF = Pumped Storage Cycle Factor - The Pumped Storage cycle factor is equal to the number of hours per day which energy may be scheduled out of Tri-State’s LAO Pumped Storage Energy account (generating hours) divided by 24 hours. Basin Electric and Tri-State agree to a deemed daily cycle of 13 hours of schedules out of and 11 hours for schedules into Tri-State’s LAO Pumped Storage Energy account, for a resultant pumped storage cycle factor of 13 divided by 24 (13/24=0.5417). The pumped storage cycle factor shall be reviewed at times to consider operating experience or changes in WAPA’s operating procedures for scheduling energy to and from the LAO Pumped Storage Energy accounts.

 

4.5.         Basin Electric Pumped Storage Replacement and Supplemental Energy Price

 

Pumped Storage Replacement Energy (PSRE) shall be billed at 18.4 mills per kilowatthour in 1989; in each subsequent year the price for PSRE shall be adjusted proportionately for increases or decreases in the energy-related production costs incurred by Basin on its entitlement deliveries from the Laramie River Station in the previous year. The price of PSRE shall not

 

11

 

exceed the then-applicable energy charges from Basin Electric to its members under its Rate Schedule A in effect at that time. Basin Electric Supplemental Energy deliveries to Tri-State shall be billed according to its Rate Schedule A in effect at that time.

 

4.6.   Incremental Demand Supplied by Basin Electric

 

The amount of Incremental Demand supplied by Basin Electric in any month shall be determined as follows:

 

BID = (NME - MEE + ELOSS - PSRE) - (0.95 * HOURS * BSD)

0.95 * HOURS

 

Where:

 

BID = Basin Electric Incremental Demand

 

NME = Tri-State’s Nebraska Metered Energy as adjusted for losses to the WAPA Points of Delivery where applicable

 

MEE = Tri-State’s Nebraska Pro Rata P-SMBP-WD Monthly Energy Entitlement as determined in Section 3.2

 

ELOSS = Losses to Adjust the Energy Supplied by Basin Electric in accordance with Section 4.1 above from Tri-State’s Points of Delivery to Stegall

 

PSRE = Pumped Storage Replacement Energy

 

BSD = Basin Electric Supplemental Demand

 

HOURS = The Number of Hours in the Billing Period

 

Provided;

 

BID shall not be less than zero

 

12

 

Basin Electric Incremental Demand shall be aggregated with the Basin Electric Supplemental Demand for billing and shall be billed in accordance with Basin Electric’s Rate Schedule A in effect at that time.

 

IN WITNESS WHEREOF, Tri-State and Basin Electric have caused this Exhibit II to be duly executed this 13th day of July, 1989.

 

	
 
    	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE 
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/George   Hargens
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
Title:   President
    
	
 
    	
 
    	
 
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
By:
    	
J.   William Keller
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
Title: Secretary
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE   GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
By:
    	
/s/H.J.   Thompson
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
Title:   President
    
	
 
    	
 
    	
 
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
By:
    	
/s/William   W. Dallas
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
Title: Secretary
    	
 
    
						

 

13

 

	
 
    	
Exhibit III
    
	
 
    	
 
    
	
 
    	
Amendment   No. 1
    
	
 
    	
to   Amended and Substituted
    
	
 
    	
Wholesale   Power Contract By
    
	
 
    	
and   Between Basin Electric
    
	
 
    	
Power   Cooperative and Tri-State
    
	
 
    	
Generation   and Transmission
    
	
 
    	
Association, Inc.
    

 

POINTS OF DELIVERY

 

This Exhibit III to Amendment No. 1 of the Amended and Substituted Wholesale Power Contract by and between Basin Electric Power Cooperative and Tri-State Generation and Transmission Association, Inc., shall become effective on the effective date of the Amendment No. 1 and shall remain in effect until superseded by a new Exhibit III or terminated upon the expiration of the Contract. (Amendment No. 1 and the Amended and Substituted Wholesale Power Contract are collectively referred to as the Contract).

 

1.                 BASIN ELECTRIC POINTS OF DELIVERY

 

Nebraska Loads

 

Sidney East 230 kV Bus

Stegall East 230 kV Bus

Wayside 230 kV Bus

Stegall West 230 kV Bus

 

Colorado/Wyoming Loads

 

Stegall West 230 kV Bus

Stegall East 230 kV Bus

Sidney East 230 kV Bus

Laramie River Station 230/345 kV Bus

 

1

 

2.                 TRI-STATE POINTS OF DELIVERY

 

Nebraska Loads

 

	
 
    	
 
    	
Required Metering
    	
 
    	
 
    	
 
    
	
Tri-State Point
    	
 
    	
Point Loss Multiplier
    	
 
    	
 
    	
 
    
	
of Delivery
    	
 
    	
Transmission
    	
 
    	
Transformer
    	
 
    	
Off-site
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Alliance Cap. Losses [1]
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Alliance S.S.
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Bushnell Tap
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Big Springs Tap [2]
    	
 
    	
1.024
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
(Blue Creek)
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Crete
    	
 
    	
1.024
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Lamar, Nebr. [3]
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Grant [4]
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Spring Creek
    	
 
    	
1.024
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Ogallala 115 kV
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
(Hyannis)
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Hemingford Tap [5]
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Ogallala 115 kV
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
N.P. (Paxton)
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
McGrew Tap
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Roscoe
    	
 
    	
1.024
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Wildhorse
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Snake Creek Tap
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
(Lynn Sub)
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Sta. Ser.
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Ogallala 12.5
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Station Service
    	
 
    	
1.040
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Sidney
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Stegall S.S.
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
West Bus
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Bayard
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Bridgeport (C.R.)
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Minatare
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.010
    	
 
    
	
Brule Tap [6]
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Midwest Rural
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Elec. Elsie
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Ogallala 34.5 kV
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Chadron
    	
 
    	
1.040
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Dunlap
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Gordon
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Whitney
    	
 
    	
1.040
    	
 
    	
1.016
    	
 
    	
1.000
    	
 
    
	
Alliance 34.5 kV
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    

 

2

 

	
 
    	
 
    	
Required Metering
    	
 
    	
 
    	
 
    
	
Tri-State Point
    	
 
    	
Point Loss Multiplier
    	
 
    	
 
    	
 
    
	
of Delivery
    	
 
    	
Transmission
    	
 
    	
Transformer
    	
 
    	
Off-site
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Box Butte
    	
 
    	
1.024
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Morrill County
    	
 
    	
1.024
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Tap [7]
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Gering Tap
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
34.5 kV (RPPD)
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    
	
Henry
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Lyman
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Mitchell
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Seivers Tap
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Jacinto Tap
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Kimball
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Sidney (Rural)
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Bridgeport Sta. Svc.
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Bridgeport 115 kV
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Bridgeport 12.5 kV
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Chappell [8]
    	
 
    	
1.040
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Colton
    	
 
    	
1.024
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Dalton Tap
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Sidney (WB)
    	
 
    	
1.060
    	
 
    	
1.000
    	
 
    	
1.000
    	
 
    
	
Wheatbelt
    	
 
    	
1.060
    	
 
    	
1.020
    	
 
    	
1.000
    	
 
    
	
Greenwood
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    	
 
    

 

[1]                      Three (3) loss meters

[2]                      Meter Adjustments: Add Wheat Belt Oshkosh, Deduct NPPD Lewellyn

[3]                      Meter Adjustments: Highline Amherst and Amity deliveries deducted

[4]                      Meter Adjustments: Deduct NPPD Brandon and Madrid deliveries and City of Grant delivery

[5]                      Meter Adjustments: Deduct NPPD Marsland delivery

[6]                      Meter Adjustments: Deduct NPPD Brule delivery

[7]                      Includes station service

[8]                      Meter Adjustments: Deduct City of Lodgepole

 

3

 

IN WITNESS WHEREOF, Tri-State and Basin Electric have caused this Exhibit III to be duly executed this 7th day of October, 1987.

 

	
 
    	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Quentin   Louden
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
Title:   President
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
By:
    	
J.   William Keller
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
Title: Secretary
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE   GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
By:
    	
/s/H.J.   Thompson
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
Title: President
    
	
 
    	
 
    	
 
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
By:
    	
/s/William   W. Dallas
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
Title: Secretary
    	
 
    	
 
    

 

4

 

REA Approval Pending

 

	
 
    	
 
    	
Exhibit IV
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
Amendment   No. 1
    
	
 
    	
 
    	
to   Amended and Substituted
    
	
 
    	
 
    	
Wholesale   Power Contract by
    
	
 
    	
SCHEDULE   A
    	
and   Between Basin Electric
    
	
 
    	
 
    	
Power   Cooperative and Tri-State
    
	
 
    	
 
    	
Generation   and Transmissions
    
	
 
    	
 
    	
Association, Inc.
    

 

Effective Date:

 

Schedule of Rates for Wholesale Firm Power Service Effective: January 1988 billing period.

 

Available:

 

To wholesale power customers for power service supplied through one meter at each of one or more points of delivery. Not applicable to stand-by or auxiliary service, except that service auxiliary to other purchased power supply will be permitted under appropriate contract terms.

 

Character and Conditions of Service

 

Alternating current, sixty cycles, three phase, delivered at specified point(s) of delivery on the Joint Transmission System and other points as defined in the Basin Electric Power Cooperative Contract with the Western Area Power Administration (WAPA), as successor to the U.S. Bureau of Reclamation, and as specified in the respective Member-Basin Electric Contract.

 

Monthly Rate:

 

Fixed Contract Rate of Delivery Members and Members who do not meet 40% purchase criteria

 

	
Demand   Charge
    	
$15.70   per kilowatt of billing   demand
    
	
Energy   Charge
    	
$.02330   per kilowatt hour
    
	
Ratchet
    	
0   percent
    
	
 
    	
 
    

All Other Members

	
 
    	
 
    
	
Base   Demand Charge
    	
$16.25   per kilowatt of billing   demand
    
	
Base   Energy Charge
    	
$.02380   per kilowatt hour
    
	
Follow-On   Demand Charge
    	
$4.00   per kilowatt of billing demand
    
	
Follow-On   Energy Charge
    	
$.017   per kilowatt hour
    
	
Ratchet
    	
0   percent
    

 

 

Load Determination:

 

The metered demand shall be the highest 30-minute Integrated demand (or corrected to a 30-minute basis in the event where 15-minute demand registers are Installed) measured during the billing period. Inasmuch as power is supplied to Class “A” Members by both the Western Area Power Administration and Basin Electric Power Cooperative trough common metering, Basin Electric Power Cooperative billings, with the exception of Tri-State Colo/Wyo, Tri-State Nebraska, Rushmore Wyoming and NIPCO billings, shall be determined as follows:

 

Where:

 

D - Shall be defined as the DEMAND - for the current billing period - determined on a basis in accordance with contract(s) in effect between the Member and WAPA.

 

E - Shall be defined as the ENERGY delivered during the billing period, as determined on a basis in accordance with contract(s) in effect between the Member and WAPA.

 

X - Shall be defined as the Contract Rate of firm power delivery as agreed to and as defined by contract(s) in effect between the Member and WAPA.

 

Y - Shall be defined as the Highest Demand (Factor ‘D’), determined in accordance with contract(s) in effect between the Member and WAPA.

 

Then:

 

BD = Basin Electric Power Cooperative monthly demand (kw).

 

BE = Basin Electric Power Cooperative monthly energy (kwh).

 

BD = D (1 - X/Y)

 

BE = E (1 - X/Y)

 

Note: The ratio X/Y shall never be more than one.

 

Basin Electric’s billed demand shall be based on its highest half hour demand delivery to the member during the subject month. The Tri-State Colo/Wyo billing shall be computed in accordance with pre-season agreed to schedules. The NIPCO billing shall be computed in accordance with the existing contract. The Tri-State Nebraska billing and Rushmore Wyoming billing shall reflect the fixed energy schedule associated with these Member’s WAPA allocations.

 

2

 

Concident Billing Adjustment:

 

Basin Electric Power Cooperative will credit the Members’ monthly power billing for diversity of load within the Members’ system using data from those points of delivery where sufficient Information is available to calculate the coincident demand adjustment. Data for the coincident demand adjustment will be measured from existing magnetic tape meters or existing strip chart meters. All meters shall be tested and calibrated as required by the wholesale power contract between Basin Electric Power Cooperative and the Member. The Member is responsible for providing and computing the necessary information for each delivery point used in the calculation. Data to calculate the coincident demand adjustment must be available the date the Members’ power billing is being processed in order to qualify for an adjustment in the current month’s power billing. Failure to receive data to calculate the adjustment will cause Basin Electric power billing for the current month to be computed on a non-coincident basis. A credit will be included in the subsequent month’s bill to reflect the Members’ diversity, provided that the Members have furnished the necessary information in the time frame required. Failure to provide said coincident billing Information within the subsequent billing month will negate the coincident demand adjustment credit for the affected billing period, except for corrections required because of equipment malfunction or other causes beyond the Members’ control. A coincident adjustment shall not be made to the Members’ qualifying load development load if this load is excluded from the Member’s x/y calculation.

 

Basis For Billing:

 

All Class A Members who during the previous 12 months purchased at least 40% of their total system demand and energy requirements from Basin Electric and who do not have fixed Basin Electric contract rates of delivery shall have the option of: 1) not participating in the Dual Heat, Incentive Commercial and Load Development rates and having their billing computed in accordance with the Follow-On/Base Rates, or 2) incorporating the features of the Dual Heat and/or Incentive Commercial and/or Load Development rates with the Follow-On/Base Rates.

 

The billing procedure for those Members selecting option 1 shall be as follows:

 

1.                      A demand base shall be established for each month of 1988 equal to 95% of the average of the Member’s 1983, 1984 and 1985 coincident demand purchases from Basin Electric.

 

2.                      An energy base shall be established for each month of 1988 equal to 95% of the average of the Member’s 1983, 1984 and 1985 energy purchases from Basin Electric.

 

3

 

3.                      The difference between the Member’s actual coincident demand supplied by Basin Electric and the established base referenced in step 1 shall be billed at the Follow-On Demand Charge.

 

4.                      The difference between the Member’s actual energy supplied by Basin Electric and the established base referenced in step 2 shall be billed at the Follow-On Energy Charge.

 

5.                      The difference between the total coincident demand supplied by Basin Electric and the follow-on demand calculated in step 3 shall be billed at the Base Demand Charge.

 

6.                      The difference between the total energy supplied by Basin Electric and the follow-on energy calculated in step 4 shall be billed at the Base Energy Charge.

 

The billing procedure for those Members selecting option 2 shall be as follows:

 

1.                      A demand base shall be established for each month of 1988 equal to 95% of the average of the Member’s 1983, 1984 and 1985 coincident demand purchases from Basin Electric.

 

2.                      An energy base shall be established for each month of 1988 equal to 95% of the average of the Member’s 1983, 1984 and 1985 energy purchases from Basin Electric.

 

3.                      The Basin Electric energy component of each Member’s commercial load, which qualifies for and is billed under the Incentive Commercial Rate, shall be subtracted from the Member’s total energy supplied by Basin Electric.

 

4.                      The Basin Electric demand component of each Member’s commercial load, which qualifies for and is billed under the Incentive Commercial Rate, shall be subtracted from the Member’s total demand supplied by Basin Electric.

 

5.                      The Basin Electric energy component of each Member’s load development load, which qualifies for and is billed under the Load Development Rate, shall be subtracted from the Member’s total energy supplied by Basin Electric.

 

6.                      The Basin Electric demand component of each Member’s load development load, which qualifies for and is billed under the Load Development Rate, shall be subtracted from the Member’s total demand supplied by Basin Electric.

 

4

 

7.                      The Basin Electric energy component of each Member’s dual heat load, which qualifies for and is billed under Dual Heat Rates 1, 2 and 3, shall be subtracted from the Member’s total energy supplied by Basin Electric.

 

8.                      The Basin Electric demand component of each Member’s dual heat load, which qualifies for and Is billed under Dual Heat Rates 1, 2, and 3, and which does not have half hour demand metering, shall be determined as follows:

 

A.                     Basin Electric’s portion of the energy used by uncontrolled dual heat Installations in accordance with Dual Heat Rate #1 shall be converted to a monthly demand assuming a 85% monthly load factor and the hours In the subject billing period.

 

B.                     Basin Electric’s portion of the energy used by uncontrolled dual heat installations in accordance with Dual Heat Rate #2 shall be converted to a monthly demand assuming a 74% monthly load factor and the hours in the subject billing period. This calculation shall only be performed for those months in which the Member kWh credit as specified in table 1 of Dual Heat Rate #2 is 35 mills/kWh.

 

C.                     Basin Electric’s portion of the energy used by uncontrolled dual heat Installations in accordance with Dual Heat Rate #3 shall be converted to a monthly demand assuming a 79% monthly load factor and the hours in the subject month.

 

9.                      The Basin Electric demand component of each Member’s dual heat load, which has half hour demand metering, qualifies and is billed according to Dual Heat Rates 1, 2 and 3, shall be determined in accordance with the provision of the dual heat rates.

 

10.               The dual heat demand calculated in steps 8 and 9 shall be totaled and subtracted from the Member’s total demand supplied by Basin Electric.

 

11.               The difference between the Member’s total demand supplied by Basin Electric adjusted per steps 4, 6 and 10, and the established base referenced in step 1, shall be billed at the Follow-On Demand Charge.

 

12.               The difference between the Member’s total energy supplied by Basin Electric adjusted per steps 3, 5 and 7, and the established base referenced in step 2, shall be billed at the Follow-On Energy Charge.

 

13.               The total demand supplied by Basin Electric less: 1) the demand billed at the Incentive Commercial rate, 2) the demand billed at the Load Development Rate, and 3) the follow-on demand calculated in step 11 shall be billed at the Base Demand Charge.

 

5

 

14.               The total energy supplied by Basin Electric less: 1) the energy billed at the Incentive Commercial Rate, 2) the energy billed at the Load Development Rate, and 3) the follow-on energy calculated in step 12 shall be billed at the Base Energy Charge.

 

15.               The load qualifying for the Incentive Commercial rate shall be billed in accordance with that rate schedule.

 

16.               The dual heat credits shall be calculated in accordance with Dual Heat Rates 1, 2 and 3.

 

17.               The load qualifying for the Load Development Rate shall be billed in accordance with that rate schedule.

 

All Class A Members who qualify for option 1 or 2, shall have the previous calculations performed in the current month provided the required coincident, dual heat, load development and commercial data is provided in sufficient time to prepare the billing. If this data is not available within the current month, the Basin Electric bill shall be computed using the Base Demand Charge and the Base Energy Charge.

 

The appropriate coincident, dual heat, load development, commercial and follow-on adjustments shall be made the following month pending the receipt of the necessary data. Failure to provide said data prior to the preparation of the subsequent month’s bill shall negate the adjustments for the affected billing month except for corrections required because of equipment malfunction or other causes beyond the Member’s control.

 

All Class A Members who have fixed Basin Electric contract rates of delivery, or who during the previous 12 months did not purchase at least 40% of their total system demand and energy requirements from Basin Electric, shall be billed at the Fixed Contract Rate of Delivery Demand and Energy Charges, which reflect what Basin Electric’s Class A Member rate would have been had the Follow-On/Base Rate concept not been adopted.

 

Tri-State Nebraska and Tri-State Colo/Wyo, shall be considered as two separate systems for the purposes of the 40% criteria.

 

NIPCO is not considered to have a Fixed Contract Rate of Delivery as their contract provides for additional purchases from Basin Electric at some future date.

 

6

 

Late Payment;

 

All Class A Member power bills will be due and payable at the Cooperative’s office in Bismarck within 15 calendar days after the bill is mailed to the Member, as provided for in the wholesale power contracts. Payments not received by the Cooperative at the Cooperative’s office in Bismarck after the 20th calendar day following billing will be assessed an Interest charge. The Interest rate charged will be revised, effective with the January and July billings of each calendar year, using the then-current seasonal loan rate of the St. Paul Bank for Cooperatives in effect as of the first day of the month and rounding it up or down to the nearest whole number.

 

Billing Periods;

 

Basin Electric Power Cooperative billing periods shall be established to coincide with the meter reading schedules of the Western Area Power Administration.

 

Adjustments for Power Factor;

 

The Member agrees to maintain unity power factor as nearly as practicable and such Member will be required to maintain an average power factor at the point of delivery of between 95 percent lagging and 95 percent leading. In the event that Basin Electric determines by test that these tolerances are exceeded, the Member shall, at his own expense, remedy the Power Factor to a value within these tolerances.

 

Delivery Facilities Participation Policy;

 

The Delivery Facilities Participation Policy approved by the Board of Directors on July 16, 1970, which became effective September 11, 1970, and as amended from time to time, is hereby Incorporated into this Schedule ‘A’, available to all Class “A” Members, upon execution of an Agreement uniform in terms.

 

Rate Continuity

 

The rate concept outlined in this schedule consisting of Follow-On and Base Charges is guaranteed for nine years (1988-1996). The Follow-On Demand Charge shall remain at $4/kW/month for the entire ten year period. The 17 mills/kWh 1988 Follow-On Energy Charge shall be adjusted annually to reflect changes in Basin Electric’s average system energy production cost. The 1988 established monthly demand and energy bases for each Member shall be maintained at that level through 1989. Each year thereafter a new base shall be calculated by dropping the first year of history and adding the next year. As an example, in 1990 the base would be equal to 95% of the average of the 1984, 1985 and 1986 historical purchases.

 

7

 

AMENDMENT NUMBER 2 TO

WHOLESALE POWER CONTRACT

BY AND BETWEEN

BASIN ELECTRIC POWER COOPERATIVE

AND

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

This Amendment No. 2 to Wholesale Power Contract is made as of this 14th day of December, 1995 , by and between Basin Electric Power Cooperative, 1717 East Interstate Avenue, Bismarck, North Dakota 58501 (“Basin Electric” or “Seller”), a North Dakota electric cooperative corporation, and Tri-State Generation and Transmission Association, Inc., a Colorado nonprofit cooperative corporation, whose principal place of business is located in or near Denver, Colorado (hereinafter “Member”).

 

WITNESSETH:

 

WHEREAS, Basin Electric and Member have heretofore entered into a certain Wholesale Power Contract dated as of August 12, 1964, as amended (“Wholesale Contract”); and

 

WHEREAS, Basin Electric is seeking certain additional loans or loan guarantees (“Loans”) from the United States, acting through the Administrator (“Administrator”) of the Rural Utilities Service (formerly the Rural Electrification Administration) or its successor agency (“RUS”); and

 

 

WHEREAS, as a condition to such Loans, the Administrator has required that the Wholesale Contract and other similar contracts between Basin Electric and its other members be amended; and

 

NOW THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereby agree as follows:

 

I.                                        The recitals contained in the Wholesale Contract are deleted and the following recitals are inserted in lieu thereof:

 

WHEREAS, Seller presently owns and operates electric generating plants, a transmission system and associated facilities, and has entered into contracts with others to provide for transmission facilities or service, or otherwise obtain electric capacity and electric energy for the purpose, among others, of supplying electric capacity and electric energy to borrowers from, including but not limited to, the Rural Utilities Service which are or may become members of Seller; and

 

WHEREAS, Seller has financed and may, in the future, finance new facilities in whole or in part through loans made or guaranteed by the United States of America (“Government”), acting through the Administrator; and

 

2

 

WHEREAS, the indebtedness created by such loans and loan guarantees made by the Government is evidenced, and, with respect to future indebtedness, shall be evidenced by certain notes (hereinafter collectively called the “Notes”), secured by that Consolidated Mortgage and Security Agreement made by and among Basin Electric Power Cooperative, Mortgagor, and the United States of America, St. Paul Bank for Cooperatives, The First National Bank of Chicago, as Trustee, Fund Asset Management, Inc., and Morgan Guaranty Trust Company of New York, as Agent, Mortgagees, dated as of November 1, 1984. (Said Consolidated Mortgage and Security Agreement as it may have heretofore been, or hereafter be, amended, supplemented and or restated from time to time being hereinafter called the Mortgage); and

 

WHEREAS, this Agreement and payments due to Seller under this Agreement will be pledged and assigned to secure the Notes, as provided in the Mortgage or other notes pursuant to other financial arrangements; and

 

WHEREAS, Member acknowledges that Seller and the Government are relying on this commitment from Member, and similar commitments from all other members having similar contracts, to purchase electric capacity and electric energy for its present and future load requirements hereunder to provide for (a) the financing of Seller’s facilities, (b) the development of an organization to serve Member, and (c) for a long-term planning and power supply acquisition program; and

 

3

 

WHEREAS, the Government is relying on this Agreement and similar contracts between Seller and other borrowers from the RUS to assure that the Notes are repaid and the purposes of the Rural Electrification Act of 1936, as amended, are carried out and Seller and Member, by executing this Amendment, acknowledge that reliance;

 

II.                                   The provision of the Wholesale Contract entitled Rate (Section 4 of the Wholesale Contract) is deleted and the following paragraphs are inserted in lieu thereof:

 

RATE. (a) Member shall pay Seller for all electric capacity and electric energy furnished hereunder at the rates and on the terms and conditions set forth in Rate Schedule “A”, attached hereto and made a part hereof, as the same may be modified from time to time by Seller.

 

(b) The Board of Directors of Seller at such intervals as it shall deem appropriate, but in any event not less frequently than once in each calendar year, shall review the rate for electric capacity and electric energy furnished hereunder and under similar contracts with other members, and, if necessary, shall revise such rate so that it shall produce revenues which shall be sufficient, but only sufficient, with the revenues of Seller from all other sources, to meet the cost of the operation and maintenance (including, without limitation, replacement, insurance, taxes and administrative and general overhead expenses) of the generating plants, the transmission system and related facilities of Seller, the cost of any capacity and

 

4

 

energy purchased for resale hereunder by Seller, the cost of transmission service, the cost of lease payments; interest expense and depreciation expense of Seller, and to provide for the establishment and maintenance of reasonable reserves. Seller shall cause a notice in writing to be given to Member and other members of Seller and the Administrator which shall set out all of the proposed revisions of rate with the effective date hereof, which shall not be less than thirty (30) nor more than forty-five (45) days after the date of the notice, and shall set forth the basis upon which the rate is proposed to be adjusted and established. The Member agrees that the rate from time to time established by the Board of Directors of Seller shall be deemed to be substituted for the rate herein provided and agrees to pay for electric capacity and electric energy furnished by Seller to it hereunder after the effective date of any such revision at such revised rates; provided, however, that no such revision shall be effective unless approved in writing by the Administrator.

 

III.                              The following additional sections are inserted in the Wholesale Contract:

 

TRANSFER BY THE MEMBER. The Member agrees that during the term of this Agreement, so long as any of the Notes are outstanding, the Member will not, without the approval in writing of Seller and the Administrator, take or suffer to be taken any steps for reorganization or to consolidate with or merge into any organization, or to sell, lease or transfer (or make any agreement therefor) all or a

 

5

 

substantial portion of its assets, whether now owned or hereafter acquired. Notwithstanding the foregoing. Member may take or suffer to be taken any steps for reorganization or to consolidate or merge into any corporation, or to sell, lease or transfer (or make any agreement therefor) all or a substantial portion of its assets, whether now owned or hereafter acquired, so long as Member shall pay such pro rata portion of the outstanding indebtedness on the Notes, as well as other obligations and commitments of Seller at the time existing, as shall be determined by Seller with the prior written consent of the Administrator and shall otherwise comply with such reasonable terms and conditions as the Administrator and Seller shall require.

 

SPECIFIC PERFORMANCE OF MEMBER. Seller and Member agree that the failure or threatened failure of Member to comply with the terms of the immediately preceding paragraph entitled Transfer by the Member will cause irreparable injury to Seller and to the Government which cannot properly or adequately be compensated by the mere payment of money. Member agrees, therefore, that in the event of a breach or threatened breach by Member of the paragraph entitled Transfer by the Member, of this Agreement, that Seller, in addition to any other remedies that may be available to it judicially, shall have the right to obtain from any competent court a decree enjoining such breach or threatened breach of said paragraph and providing for the terms of said paragraph to be specifically enforced.

 

6

 

IV.                               The provision entitled Term in the Wholesale Contract, as amended, is hereby amended deleting the date appearing therein and substituting the date “December 31, 2025.”

 

V.                                    Except as amended hereby, the provision of the Wholesale Contract shall remain in full force and effect; provided, however, that to the extent any of the amending provisions hereof shall conflict with any other provision of the Wholesale Contract, this Amendment shall supersede such provision.

 

Executed as of the day and year first above written.

 

	
(SEAL)
    	
 
    	
BASIN   ELECTRIC POWER
    
	
 
    	
 
    	
COOPERATIVE
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Bill   Wagner
    
	
Michael   J. Hinman
    	
 
    	
Its:
    	
President
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE   GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION   ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
Attest:
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/H.J.   Thompson
    
	
/s/William   W. Dallas
    	
 
    	
Its:
    	
President
    
	
Secretary
    	
 
    	
 
    

 

7

 

AMENDMENT NUMBER 3 TO

WHOLESALE POWER CONTRACT

BY AND BETWEEN

BASIN ELECTRIC POWER COOPERATIVE

AND

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

This Amendment No. 3 to· Wholesale Power Contract is made as of this 1st day of July, 2002, by and between Basin Electric Power Cooperative, 1717 East Interstate Avenue, Bismarck, North Dakota 58503 (“Basin Electric” or “Seller”), a North Dakota electric cooperative corporation, and Tri-State Generation and Transmission Association, Inc., a Colorado nonprofit cooperative corporation whose principal place of business is located in or near Denver, Colorado (hereinafter “Member”).

 

WITNESSETH:

 

WHEREAS, Basin Electric and Member have heretofore entered into a certain Wholesale Power Contract dated as of August 12, 1964, as amended (“Wholesale Power Contract”); and

 

WHEREAS, Basin Electric desires to sell and Tri-State desires to purchase additional power pursuant to the Wholesale Power Contract for Member’s Colorado/Wyoming system.

 

NOW THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereby agree to amend the Wholesale Power Contract as follows:

 

1.                                      Amount of Sale:

 

Section 1 A shall be deleted in its entirety and the following substituted in lieu thereof:

 

“Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive

 

1

 

from Basin Electric 100,000 kW of capacity and energy for Tri-State loads in Colorado/Wyoming.

 

Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric an additional 25, 000 kW of capacity and energy for Tri-State’s loads in Colorado/Wyoming beginning August 1, 2002. Notwithstanding Exhibit III, this 25,000 kW shall be delivered to the Ault or Story 230 kV MBPP bus. In the event Basin Electric is experiencing transmission constraints between LRS and the Ault and/or Story 230 kV bus, Basin Electric will curtail this delivery on a pro-rata basis with its other firm deliveries to Ault and/or Story, and will deliver a portion or all of this 25,000 kW to the LRS 230/345 kV bus or the Stegall West 230 kV bus.

 

Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric a further additional 25,000 kW of capacity and energy for Tri-State’s loads in Colorado/Wyoming following the commercial operation of the Rapid City DC Tie (anticipated, but not guaranteed, to be late 2003 or early 2004). Notwithstanding Exhibit III, this 25,000 kW shall be delivered to the Ault or Story 230 kV MBPP bus. In the event Basin Electric is experiencing transmission constraints between LRS and the Ault and/or Story 230 kV bus, Basin Electric will curtail this delivery on a pro-rata basis with its other firm deliveries to Ault and/or Story, and will deliver a portion or all of this 25,000 kW to the LRS 230/345 kV bus or the Stegall West 230 kV bus.

 

The capacity and energy shall be furnished in accordance with the normal seasonal load pattern of Tri-State’s Colorado/Wyoming system and shall reflect a 100,000 kW (125,000) (150,000) kW schedule in at least one month of each season (winter and summer). The scheduling procedures and energy loss provisions are provided for in Exhibit I attached

 

2

 

hereto.

 

For the purpose of determining payment for transmission losses, it shall be assumed all power is delivered at the LRS bus.”

 

2.              Rate:

 

The Section 4 entitled “Rate (A)” is hereby amended by adding the following language:

 

“Notwithstanding the foregoing, neither the additional 25,000kW sale beginning August 1, 2002, nor the further additional 25,000 kW sale following commercial operation of the Rapid City DC Tie shall be priced to reflect the power cost adjustment accumulated to the date of execution of this Amendment Number 3.”

 

3.              Term:

 

The section entitled “Term” is hereby amended by deleting the date appearing therein and substituting the date December 31, 2040.

 

4.              Validity of Wholesale Power Contract:

 

Except as amended hereby, the provisions of the Wholesale Power Contract shall remain in full force and effect provided, however, that to the extent any of the amending provisions hereof shall conflict with any other provision of the Wholesale Power Contract, this amendment shall supersede such provision.

 

5.              Approval of Administrator of Rural Utilities Service:

 

The execution of this Amendment Number 3 to the Wholesale Power Contract between Basin Electric and Member is subject to the approval of the Administrator of the Rural

 

3

 

Utilities Service under the terms of the loan contracts entered into with the Administrator by Basin Electric and Member, respectively, and shall be of no force and effect until the provisions of those loan contracts specifically, but not limited to Sections 6.7 and 9.1 of the Amended and Consolidated Loan Contract dated January 1, 1998 between Basin Electric Power Cooperative and the United States of America have been met.

 

Executed as of the day and year first above written.

 

	
(SEAL)
    	
 
    	
BASIN ELECTRIC POWER COOPERATIVE
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Ronald   R. Harper
    
	
Attest:
    	
 
    	
 
    	
Ronald   R. Harper
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Its:
    	
CEO &   General Manager
    
	
By:
    	
/S/Clair   M. Olson
    	
 
    	
 
    
	
Claire   M. Olson
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
Its:   Assistant Secretary
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
ATTEST:
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
By:
    	
/s/Frank   R. Knutson
    
	
By:
    	
/s/Robert   E. Temmer
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Its:
    	
Executive   VP/ General Manager
    
	
 
    	
 
    	
 
    	
 
    
	
Its:
    	
Sr.   VP/General Counsel
    	
 
    	
 
    

 

4

 

AMENDMENT NUMBER 4 TO THE

AMENDED AND SUBSTITUTED

WHOLESALE POWER CONTRACT

BY AND BETWEEN

BASIN ELECTRIC POWER COOPERATIVE

AND

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

This Amendment No. 4 to the Amended and Substituted Wholesale Power Contract is made as of this 24th day of November, 2004, by and between Basin Electric Power Cooperative, 1717 East Interstate Avenue, Bismarck, North Dakota 58503 (“Basin Electric” or “Seller”), a North Dakota electric cooperative corporation, and Tri-State Generation and Transmission Association, Inc., a Colorado nonprofit cooperative corporation whose principal place of business is located in or near Denver, Colorado (hereinafter “Member”).

 

WITNESSETH:

 

WHEREAS, Basin Electric and Member have heretofore entered into a certain Wholesale Power Contract dated as of August 12, 1964, as amended, which was replaced by the Amended and Substituted Wholesale Power Contract dated January 16, 1975, as amended (“Wholesale Power Contract”); and

 

WHEREAS, Basin Electric desires to sell and Tri-State desires to purchase additional power pursuant to the Wholesale Power Contract for Member’s Colorado/Wyoming system and to delete the upper limit on Basin Electric’s sales to the Member’s Nebraska loads;

 

NOW THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereby agree to amend the Wholesale Power Contract as follows:

 

1

 

1.              Amount of Sale:

 

(A)                               Section 1A shall be deleted in its entirety and the following substituted in lieu thereof:

 

“(i)                               Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric 100,000 kW of capacity and energy for Tri-State loads in Colorado/Wyoming per Exhibit III. The scheduling procedures and energy loss provisions are provided for in Exhibit I.

 

(ii)                                  Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric an additional 50,000 kW of capacity and energy for Tri-State’s loads in Colorado/Wyoming. Notwithstanding Exhibit III, this 50,000 kW shall be delivered to the Ault or Story 230 kV MBPP bus. In the event Basin Electric is experiencing transmission constraints between LRS and the Ault and/or Story 230 kV bus, Basin Electric will curtail this delivery on a pro-rata basis with its other firm deliveries to Ault and/or Story, and will deliver a portion or all of this 50,000 kW to the LRS 230/345 kV bus or the Stegall West 230 kV bus. The scheduling procedures and energy loss provisions are provided for in Exhibit IA.

 

(iii)                               Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric a further additional 75,000 kW of capacity and energy for Tri-State’s loads in Colorado/Wyoming following the commercial date of a new coal based resource in Wyoming owned by Basin Electric (anticipated, but not guaranteed, to be in 2011). Notwithstanding Exhibit III, this 75,000 kW shall be delivered to the Ault or Story 230 kV MBPP bus. In

 

2

 

the event Basin Electric is experiencing transmission constraints between LRS and the Ault and/or Story 230 kV bus. Basin Electric will curtail this delivery on a pro-rata basis with its other firm deliveries to Ault and/or Story, and will deliver a portion or all of this 75,000 kW to the LRS 230/345 kV bus or the Stegall West 230 kV bus. The scheduling procedures and energy loss provisions are specified in Exhibit 1A.

 

(iv)                              For the purpose of determining payment for transmission losses, it shall be assumed all power sold under Section 1(A) is delivered at the LRS bus.”

 

(B)                               Section 1(B) shall be deleted in its entirety and the following is substituted in lieu thereof:

 

“B. Basin Electric shall sell and deliver to Tri-State and Tri-State shall purchase and receive from Basin Electric for its Nebraska loads all electric capacity and energy which Tri-State shall require in addition to the capacity and energy available to Tri-State from the Western Area Power Administration (WAPA). The amount of WAPA capacity and energy available for use for the Nebraska loads and provisions for supplemental power are set forth in Exhibit II.”

 

2.              Rate:

 

Section 4 entitled “RATE” (A) is hereby amended by deleting the following language:

 

“Notwithstanding the foregoing, neither the additional 25,000 kW sale beginning August 1, 2002, nor the further additional 25, 000 kW sale

 

3

 

following commercial operation of the Rapid City DC Tie shall be priced to reflect the power cost adjustment accumulated to the date of execution of this Amendment Number 3.”

 

Section 4 entitled “RATE” (A) is hereby amended by adding the following:

 

“Notwithstanding the foregoing, the additional 50,000 kW sale shall not be priced to reflect the power cost adjustment accumulated to the date of execution of Amendment Number 3. The further additional 75,000 kW sale following the commercial date of a new coal based resource in Wyoming owned by Basin Electric, shall not be priced to reflect the power cost adjustment accumulated to the date of execution of this Amendment Number 4.”

 

3.              Exhibit I:

 

Exhibit I, Section 2 shall be deleted in its entirety and the following substituted in lieu thereof:

 

“Tri-State shall prepare and submit two monthly schedules to Basin Electric and its agents for capacity and energy deliveries to Colorado-Wyoming. These schedules shall be for loads located electrically west and electrically east of the east-west electrical separation and shall generally conform to the normal load patterns of the loads being served. The sum of the schedules shall equal the amounts established in Table 1 (attached hereto) of this Exhibit I. The schedules in Table 1 may be

 

4

 

modified by mutual agreement.”

 

4.              Exhibit IA:

 

The attached Exhibit IA is hereby added as a new and additional exhibit to the Wholesale Power Contract.

 

5.              Validity of Wholesale Power Contract:

 

Except as amended hereby, the provisions of the Wholesale Power Contract shall remain in full force and effect provided, however, that to the extent any of the amending provisions hereof shall conflict with any other provision of the Wholesale Power Contract, this amendment shall supersede such provision.

 

6.              Approval of Administrator of Rural Utilities Service:

 

The execution of this Amendment Number 4 to the to the Amended and Substituted Wholesale Power Contract between Basin Electric and Member is subject to the approval of the Administrator of the Rural Utilities Service under the terms of the loan contracts entered into with the Administrator by Basin Electric and Member, respectively, and shall be of no force and effect until the provisions of those loan contracts specifically, but not limited to Sections 6.7 and 9.1 of the Amended and Consolidated Loan Contract dated January 1, 1998 between Basin Electric Power Cooperative and the United States of America have been met.

 

5

 

Executed as of the day and year first above written.

 

	
(SEAL)
    	
 
    	
BASIN ELECTRIC POWER COOPERATIVE
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Ronald   R. Harper
    
	
Attest:
    	
 
    	
 
    	
Ronald   R. Harper
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Its:
    	
CEO &   General Manager
    
	
By:
    	
/S/Clair M. Olson
    	
 
    	
 
    
	
Claire   M. Olson
    	
 
    	
Date:   November 2, 2004
    
	
 
    	
 
    	
 
    
	
Its:
    	
Secretary
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Micheal   S. McInnis for JM Shafer
    
	
:   Witnessed
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
By:
    	
/s/Glenda Lanik
    	
 
    	
Its:
    	
Executive   Vice President/ General Manager
    
	
 
    	
 
    	
 
    	
 
    
	
Its:
    	
Assistant General Counsel
    	
 
    	
Date:   November 24, 2004
    

 

6

 

Exhibit I

Table 1

 

	
 
    	
 
    	
MONTHLY SCHEDULE SHAPES
    	
 
    	
Day
    	
 
    
	
Month\HE
    	
 
    	
01
    	
 
    	
02
    	
 
    	
03
    	
 
    	
04
    	
 
    	
05
    	
 
    	
06
    	
 
    	
07
    	
 
    	
08
    	
 
    	
09
    	
 
    	
10
    	
 
    	
11
    	
 
    	
12
    	
 
    	
13
    	
 
    	
14
    	
 
    	
15
    	
 
    	
16
    	
 
    	
17
    	
 
    	
18
    	
 
    	
19
    	
 
    	
20
    	
 
    	
21
    	
 
    	
22
    	
 
    	
23
    	
 
    	
24
    	
 
    	
Total
    	
 
    
	
JAN
    	
 
    	
74
    	
 
    	
73
    	
 
    	
72
    	
 
    	
72
    	
 
    	
74
    	
 
    	
79
    	
 
    	
87
    	
 
    	
90
    	
 
    	
89
    	
 
    	
88
    	
 
    	
86
    	
 
    	
85
    	
 
    	
82
    	
 
    	
81
    	
 
    	
79
    	
 
    	
80
    	
 
    	
83
    	
 
    	
94
    	
 
    	
97
    	
 
    	
95
    	
 
    	
94
    	
 
    	
90
    	
 
    	
83
    	
 
    	
77
    	
 
    	
2004
    	
 
    
	
FEB
    	
 
    	
76
    	
 
    	
75
    	
 
    	
75
    	
 
    	
75
    	
 
    	
77
    	
 
    	
82
    	
 
    	
89
    	
 
    	
91
    	
 
    	
90
    	
 
    	
89
    	
 
    	
88
    	
 
    	
86
    	
 
    	
83
    	
 
    	
82
    	
 
    	
81
    	
 
    	
81
    	
 
    	
83
    	
 
    	
89
    	
 
    	
97
    	
 
    	
96
    	
 
    	
94
    	
 
    	
91
    	
 
    	
85
    	
 
    	
79
    	
 
    	
2034
    	
 
    
	
MAR
    	
 
    	
75
    	
 
    	
74
    	
 
    	
74
    	
 
    	
74
    	
 
    	
76
    	
 
    	
81
    	
 
    	
87
    	
 
    	
90
    	
 
    	
90
    	
 
    	
90
    	
 
    	
88
    	
 
    	
87
    	
 
    	
85
    	
 
    	
83
    	
 
    	
82
    	
 
    	
82
    	
 
    	
83
    	
 
    	
86
    	
 
    	
95
    	
 
    	
97
    	
 
    	
95
    	
 
    	
91
    	
 
    	
84
    	
 
    	
78
    	
 
    	
2027
    	
 
    
	
APR
    	
 
    	
52
    	
 
    	
51
    	
 
    	
51
    	
 
    	
51
    	
 
    	
52
    	
 
    	
56
    	
 
    	
61
    	
 
    	
63
    	
 
    	
64
    	
 
    	
64
    	
 
    	
64
    	
 
    	
63
    	
 
    	
62
    	
 
    	
61
    	
 
    	
61
    	
 
    	
60
    	
 
    	
61
    	
 
    	
61
    	
 
    	
63
    	
 
    	
65
    	
 
    	
68
    	
 
    	
66
    	
 
    	
60
    	
 
    	
55
    	
 
    	
1435
    	
 
    
	
MAY
    	
 
    	
60
    	
 
    	
59
    	
 
    	
58
    	
 
    	
58
    	
 
    	
59
    	
 
    	
61
    	
 
    	
67
    	
 
    	
70
    	
 
    	
72
    	
 
    	
73
    	
 
    	
73
    	
 
    	
73
    	
 
    	
73
    	
 
    	
73
    	
 
    	
72
    	
 
    	
72
    	
 
    	
73
    	
 
    	
73
    	
 
    	
73
    	
 
    	
74
    	
 
    	
77
    	
 
    	
76
    	
 
    	
70
    	
 
    	
64
    	
 
    	
1653
    	
 
    
	
JUN
    	
 
    	
71
    	
 
    	
69
    	
 
    	
67
    	
 
    	
66
    	
 
    	
67
    	
 
    	
69
    	
 
    	
73
    	
 
    	
78
    	
 
    	
82
    	
 
    	
84
    	
 
    	
86
    	
 
    	
88
    	
 
    	
88
    	
 
    	
89
    	
 
    	
89
    	
 
    	
90
    	
 
    	
90
    	
 
    	
91
    	
 
    	
90
    	
 
    	
89
    	
 
    	
90
    	
 
    	
91
    	
 
    	
84
    	
 
    	
77
    	
 
    	
1958
    	
 
    
	
JUL
    	
 
    	
78
    	
 
    	
75
    	
 
    	
74
    	
 
    	
73
    	
 
    	
73
    	
 
    	
74
    	
 
    	
77
    	
 
    	
83
    	
 
    	
87
    	
 
    	
91
    	
 
    	
94
    	
 
    	
96
    	
 
    	
97
    	
 
    	
98
    	
 
    	
99
    	
 
    	
100
    	
 
    	
100
    	
 
    	
100
    	
 
    	
99
    	
 
    	
98
    	
 
    	
97
    	
 
    	
97
    	
 
    	
90
    	
 
    	
83
    	
 
    	
2133
    	
 
    
	
AUG
    	
 
    	
77
    	
 
    	
75
    	
 
    	
74
    	
 
    	
73
    	
 
    	
73
    	
 
    	
75
    	
 
    	
79
    	
 
    	
83
    	
 
    	
87
    	
 
    	
90
    	
 
    	
92
    	
 
    	
94
    	
 
    	
95
    	
 
    	
96
    	
 
    	
97
    	
 
    	
98
    	
 
    	
98
    	
 
    	
98
    	
 
    	
98
    	
 
    	
96
    	
 
    	
98
    	
 
    	
95
    	
 
    	
87
    	
 
    	
81
    	
 
    	
2109
    	
 
    
	
SEP
    	
 
    	
61
    	
 
    	
60
    	
 
    	
59
    	
 
    	
58
    	
 
    	
59
    	
 
    	
63
    	
 
    	
69
    	
 
    	
71
    	
 
    	
73
    	
 
    	
75
    	
 
    	
75
    	
 
    	
76
    	
 
    	
76
    	
 
    	
76
    	
 
    	
77
    	
 
    	
77
    	
 
    	
77
    	
 
    	
78
    	
 
    	
79
    	
 
    	
82
    	
 
    	
82
    	
 
    	
78
    	
 
    	
71
    	
 
    	
64
    	
 
    	
1716
    	
 
    
	
OCT
    	
 
    	
65
    	
 
    	
64
    	
 
    	
63
    	
 
    	
63
    	
 
    	
65
    	
 
    	
69
    	
 
    	
77
    	
 
    	
80
    	
 
    	
80
    	
 
    	
80
    	
 
    	
79
    	
 
    	
78
    	
 
    	
77
    	
 
    	
77
    	
 
    	
76
    	
 
    	
76
    	
 
    	
77
    	
 
    	
79
    	
 
    	
83
    	
 
    	
86
    	
 
    	
84
    	
 
    	
80
    	
 
    	
74
    	
 
    	
68
    	
 
    	
1800
    	
 
    
	
NOV
    	
 
    	
76
    	
 
    	
75
    	
 
    	
75
    	
 
    	
75
    	
 
    	
76
    	
 
    	
81
    	
 
    	
88
    	
 
    	
90
    	
 
    	
89
    	
 
    	
89
    	
 
    	
87
    	
 
    	
86
    	
 
    	
84
    	
 
    	
83
    	
 
    	
82
    	
 
    	
82
    	
 
    	
87
    	
 
    	
97
    	
 
    	
98
    	
 
    	
97
    	
 
    	
95
    	
 
    	
91
    	
 
    	
85
    	
 
    	
79
    	
 
    	
2047
    	
 
    
	
DEC
    	
 
    	
77
    	
 
    	
75
    	
 
    	
75
    	
 
    	
75
    	
 
    	
76
    	
 
    	
80
    	
 
    	
87
    	
 
    	
90
    	
 
    	
89
    	
 
    	
39
    	
 
    	
87
    	
 
    	
85
    	
 
    	
83
    	
 
    	
81
    	
 
    	
80
    	
 
    	
81
    	
 
    	
87
    	
 
    	
99
    	
 
    	
100
    	
 
    	
99
    	
 
    	
97
    	
 
    	
94
    	
 
    	
87
    	
 
    	
80
    	
 
    	
2053
    	
 
    

 

7

 

Exhibit IA

 

Colorado-Wyoming Deliveries

 

This Exhibit IA to Amendment No. 4 of the Amended and Substituted Wholesale Power Contract by and between Basin Electric Power Cooperative and Tri-State Generation and Transmission Association, Inc., shall become effective on the effective date of the Amendment No. 4 and shall remain in effect until superseded by a new Exhibit IA or terminated upon the expiration of the Wholesale Power Contract.

 

1.                                      Written Scheduling, Accounting and Billing Procedures for Colorado-Wyoming Deliveries under Section 1(A)(ii) and 1(A)(iii) of the Wholesale Power Contract shall be developed and agreed upon by representatives of Tri-State and Basin Electric. The Scheduling, Accounting and Billing Procedures are intended to implement the terms of the Wholesale Power Contract but not to modify or amend it.

 

2.                                      The monthly schedules are attached hereto as Tables 1 and 2. Table 1 shall apply to the deliveries per Sections l(A)(ii). Table 2 shall apply to the deliveries per Section l(A)(iii). These schedules may be modified by mutual agreement.

 

3.                                      Tri-State shall bear the responsibility and costs associated with the transmission of capacity and energy beyond Basin Electric’s Points of Delivery as stated in Section 1(A)(ii) and 1(A)(iii) of the Wholesale Power Contract. This shall include, but not be limited to, wheeling, losses and control power charges.

 

8

 

IN WITNESS WHEREOF, Tri-State and Basin Electric have caused this Exhibit IA to be duly executed this 2nd day of November, 2004.

 

	
(SEAL)
    	
 
    	
BASIN ELECTRIC POWER COOPERATIVE
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Ronald   R. Harper
    
	
Attest:
    	
 
    	
 
    	
Ronald   R. Harper
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
Its:
    	
CEO &   General Manager
    
	
By:
    	
/S/Clair   M. Olson
    	
 
    	
 
    
	
Claire   M. Olson
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
Its:
    	
Assistant   Secretary
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE GENERATION AND
    
	
 
    	
 
    	
TRANSMISSION ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    
	
(SEAL)
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Micheal   S. McInnis for JM Shafer
    
	
:   Witnessed
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    	
 
    
	
By:
    	
/s/Glenda   Lanik
    	
 
    	
Its:
    	
Executive   Vice President/ General Manager
    
	
 
    	
 
    	
 
    	
 
    
	
Its:
    	
Assistant   General Counsel
    	
 
    	
 
    

 

9

 

Exhibit IA

Table 1

 

	
 
    	
 
    	
MONTHLY SCHEDULE SHAPES
    	
 
    	
Day
    	
 
    
	
Month\HE
    	
 
    	
01
    	
 
    	
02
    	
 
    	
03
    	
 
    	
04
    	
 
    	
05
    	
 
    	
06
    	
 
    	
07
    	
 
    	
08
    	
 
    	
09
    	
 
    	
10
    	
 
    	
11
    	
 
    	
12
    	
 
    	
13
    	
 
    	
14
    	
 
    	
15
    	
 
    	
16
    	
 
    	
17
    	
 
    	
18
    	
 
    	
19
    	
 
    	
20
    	
 
    	
21
    	
 
    	
22
    	
 
    	
23
    	
 
    	
24
    	
 
    	
Total
    	
 
    
	
JAN
    	
 
    	
37
    	
 
    	
37
    	
 
    	
36
    	
 
    	
37
    	
 
    	
37
    	
 
    	
40
    	
 
    	
44
    	
 
    	
45
    	
 
    	
45
    	
 
    	
45
    	
 
    	
44
    	
 
    	
43
    	
 
    	
41
    	
 
    	
41
    	
 
    	
40
    	
 
    	
40
    	
 
    	
42
    	
 
    	
47
    	
 
    	
49
    	
 
    	
48
    	
 
    	
47
    	
 
    	
46
    	
 
    	
42
    	
 
    	
39
    	
 
    	
1012
    	
 
    
	
FEB
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
39
    	
 
    	
41
    	
 
    	
45
    	
 
    	
46
    	
 
    	
46
    	
 
    	
45
    	
 
    	
44
    	
 
    	
43
    	
 
    	
42
    	
 
    	
41
    	
 
    	
41
    	
 
    	
41
    	
 
    	
42
    	
 
    	
45
    	
 
    	
49
    	
 
    	
49
    	
 
    	
48
    	
 
    	
46
    	
 
    	
43
    	
 
    	
40
    	
 
    	
1028
    	
 
    
	
MAR
    	
 
    	
38
    	
 
    	
38
    	
 
    	
37
    	
 
    	
38
    	
 
    	
38
    	
 
    	
41
    	
 
    	
44
    	
 
    	
46
    	
 
    	
46
    	
 
    	
45
    	
 
    	
44
    	
 
    	
44
    	
 
    	
43
    	
 
    	
42
    	
 
    	
42
    	
 
    	
42
    	
 
    	
42
    	
 
    	
44
    	
 
    	
48
    	
 
    	
49
    	
 
    	
48
    	
 
    	
46
    	
 
    	
43
    	
 
    	
39
    	
 
    	
1027
    	
 
    
	
APR
    	
 
    	
26
    	
 
    	
26
    	
 
    	
25
    	
 
    	
25
    	
 
    	
26
    	
 
    	
28
    	
 
    	
30
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
31
    	
 
    	
31
    	
 
    	
30
    	
 
    	
30
    	
 
    	
30
    	
 
    	
31
    	
 
    	
31
    	
 
    	
32
    	
 
    	
34
    	
 
    	
33
    	
 
    	
30
    	
 
    	
27
    	
 
    	
716
    	
 
    
	
MAY
    	
 
    	
30
    	
 
    	
30
    	
 
    	
29
    	
 
    	
29
    	
 
    	
30
    	
 
    	
31
    	
 
    	
34
    	
 
    	
36
    	
 
    	
36
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
39
    	
 
    	
39
    	
 
    	
36
    	
 
    	
32
    	
 
    	
838
    	
 
    
	
JUN
    	
 
    	
36
    	
 
    	
35
    	
 
    	
34
    	
 
    	
34
    	
 
    	
34
    	
 
    	
35
    	
 
    	
37
    	
 
    	
40
    	
 
    	
41
    	
 
    	
43
    	
 
    	
44
    	
 
    	
.44
    	
 
    	
45
    	
 
    	
45
    	
 
    	
45
    	
 
    	
45
    	
 
    	
46
    	
 
    	
46
    	
 
    	
46
    	
 
    	
45
    	
 
    	
46
    	
 
    	
46
    	
 
    	
43
    	
 
    	
39
    	
 
    	
994
    	
 
    
	
JUL
    	
 
    	
39
    	
 
    	
38
    	
 
    	
37
    	
 
    	
36
    	
 
    	
36
    	
 
    	
37
    	
 
    	
39
    	
 
    	
41
    	
 
    	
44
    	
 
    	
45
    	
 
    	
47
    	
 
    	
48
    	
 
    	
49
    	
 
    	
49
    	
 
    	
50
    	
 
    	
50
    	
 
    	
50
    	
 
    	
50
    	
 
    	
50
    	
 
    	
49
    	
 
    	
49
    	
 
    	
48
    	
 
    	
45
    	
 
    	
41
    	
 
    	
1067
    	
 
    
	
AUG
    	
 
    	
39
    	
 
    	
38
    	
 
    	
37
    	
 
    	
36
    	
 
    	
37
    	
 
    	
38
    	
 
    	
39
    	
 
    	
42
    	
 
    	
43
    	
 
    	
45
    	
 
    	
46
    	
 
    	
47
    	
 
    	
48
    	
 
    	
48
    	
 
    	
49
    	
 
    	
49
    	
 
    	
49
    	
 
    	
49
    	
 
    	
49
    	
 
    	
.   48
    	
 
    	
49
    	
 
    	
47
    	
 
    	
44
    	
 
    	
40
    	
 
    	
1056
    	
 
    
	
SEP
    	
 
    	
31
    	
 
    	
30
    	
 
    	
29
    	
 
    	
29
    	
 
    	
30
    	
 
    	
31
    	
 
    	
34
    	
 
    	
36
    	
 
    	
37
    	
 
    	
37
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
39
    	
 
    	
39
    	
 
    	
39
    	
 
    	
41
    	
 
    	
41
    	
 
    	
39
    	
 
    	
35
    	
 
    	
32
    	
 
    	
857
    	
 
    
	
OCT
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
32
    	
 
    	
35
    	
 
    	
39
    	
 
    	
40
    	
 
    	
40
    	
 
    	
40
    	
 
    	
40
    	
 
    	
39
    	
 
    	
39
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
40
    	
 
    	
42
    	
 
    	
43
    	
 
    	
42
    	
 
    	
40
    	
 
    	
37
    	
 
    	
34
    	
 
    	
902
    	
 
    
	
NOV
    	
 
    	
38
    	
 
    	
37
    	
 
    	
37
    	
 
    	
37
    	
 
    	
38
    	
 
    	
41
    	
 
    	
44
    	
 
    	
45
    	
 
    	
45
    	
 
    	
44
    	
 
    	
44
    	
 
    	
43
    	
 
    	
42
    	
 
    	
41
    	
 
    	
41
    	
 
    	
41
    	
 
    	
43
    	
 
    	
48
    	
 
    	
49
    	
 
    	
48
    	
 
    	
47
    	
 
    	
46
    	
 
    	
42
    	
 
    	
40
    	
 
    	
1021
    	
 
    
	
DEC
    	
 
    	
38
    	
 
    	
38
    	
 
    	
37
    	
 
    	
37
    	
 
    	
38
    	
 
    	
40
    	
 
    	
44
    	
 
    	
45
    	
 
    	
45
    	
 
    	
44
    	
 
    	
43
    	
 
    	
42
    	
 
    	
41
    	
 
    	
41
    	
 
    	
40
    	
 
    	
40
    	
 
    	
44
    	
 
    	
49
    	
 
    	
50
    	
 
    	
50
    	
 
    	
49
    	
 
    	
47
    	
 
    	
44
    	
 
    	
40
    	
 
    	
1026
    	
 
    

 

10

 

Exhibit IA

Table 2

 

	
 
    	
 
    	
MONTHLY SCHEDULE SHAPES
    	
 
    	
Day
    	
 
    
	
Month\HE
    	
 
    	
01
    	
 
    	
02
    	
 
    	
03
    	
 
    	
04
    	
 
    	
05
    	
 
    	
06
    	
 
    	
07
    	
 
    	
08
    	
 
    	
09
    	
 
    	
10
    	
 
    	
11
    	
 
    	
12
    	
 
    	
13
    	
 
    	
14
    	
 
    	
15
    	
 
    	
16
    	
 
    	
17
    	
 
    	
18
    	
 
    	
19
    	
 
    	
20
    	
 
    	
21
    	
 
    	
22
    	
 
    	
23
    	
 
    	
24
    	
 
    	
Total
    	
 
    
	
JAN
    	
 
    	
56
    	
 
    	
55
    	
 
    	
54
    	
 
    	
54
    	
 
    	
56
    	
 
    	
59
    	
 
    	
65
    	
 
    	
68
    	
 
    	
67
    	
 
    	
66
    	
 
    	
65
    	
 
    	
64
    	
 
    	
62
    	
 
    	
61
    	
 
    	
59
    	
 
    	
60
    	
 
    	
62
    	
 
    	
71
    	
 
    	
73
    	
 
    	
71
    	
 
    	
71
    	
 
    	
68
    	
 
    	
62
    	
 
    	
58
    	
 
    	
1507
    	
 
    
	
FEB
    	
 
    	
57
    	
 
    	
56
    	
 
    	
56
    	
 
    	
56
    	
 
    	
58
    	
 
    	
62
    	
 
    	
67
    	
 
    	
68
    	
 
    	
68
    	
 
    	
67
    	
 
    	
66
    	
 
    	
65
    	
 
    	
62
    	
 
    	
62
    	
 
    	
61
    	
 
    	
61
    	
 
    	
62
    	
 
    	
67
    	
 
    	
73
    	
 
    	
72
    	
 
    	
71
    	
 
    	
68
    	
 
    	
64
    	
 
    	
59
    	
 
    	
1528
    	
 
    
	
MAR
    	
 
    	
56
    	
 
    	
56
    	
 
    	
56
    	
 
    	
56
    	
 
    	
57
    	
 
    	
61
    	
 
    	
65
    	
 
    	
68
    	
 
    	
68
    	
 
    	
68
    	
 
    	
66
    	
 
    	
65
    	
 
    	
64
    	
 
    	
62
    	
 
    	
62
    	
 
    	
62
    	
 
    	
62
    	
 
    	
65
    	
 
    	
71
    	
 
    	
73
    	
 
    	
71
    	
 
    	
68
    	
 
    	
63
    	
 
    	
59
    	
 
    	
1524
    	
 
    
	
APR
    	
 
    	
39
    	
 
    	
38
    	
 
    	
38
    	
 
    	
38
    	
 
    	
39
    	
 
    	
42
    	
 
    	
46
    	
 
    	
47
    	
 
    	
48
    	
 
    	
48
    	
 
    	
48
    	
 
    	
47
    	
 
    	
47
    	
 
    	
46
    	
 
    	
46
    	
 
    	
45
    	
 
    	
46
    	
 
    	
46
    	
 
    	
47
    	
 
    	
49
    	
 
    	
51
    	
 
    	
50
    	
 
    	
45
    	
 
    	
41
    	
 
    	
1077
    	
 
    
	
MAY
    	
 
    	
45
    	
 
    	
44
    	
 
    	
44
    	
 
    	
44
    	
 
    	
44
    	
 
    	
46
    	
 
    	
50
    	
 
    	
53
    	
 
    	
54
    	
 
    	
55
    	
 
    	
55
    	
 
    	
55
    	
 
    	
55
    	
 
    	
55
    	
 
    	
54
    	
 
    	
54
    	
 
    	
55
    	
 
    	
55
    	
 
    	
55
    	
 
    	
56
    	
 
    	
58
    	
 
    	
57
    	
 
    	
53
    	
 
    	
48
    	
 
    	
1244
    	
 
    
	
JUN
    	
 
    	
53
    	
 
    	
52
    	
 
    	
50
    	
 
    	
50
    	
 
    	
50
    	
 
    	
52
    	
 
    	
55
    	
 
    	
59
    	
 
    	
62
    	
 
    	
63
    	
 
    	
65
    	
 
    	
66
    	
 
    	
66
    	
 
    	
67
    	
 
    	
67
    	
 
    	
68
    	
 
    	
68
    	
 
    	
68
    	
 
    	
68
    	
 
    	
67
    	
 
    	
68
    	
 
    	
68
    	
 
    	
63
    	
 
    	
58
    	
 
    	
1473
    	
 
    
	
JUL
    	
 
    	
59
    	
 
    	
56
    	
 
    	
56
    	
 
    	
55
    	
 
    	
55
    	
 
    	
56
    	
 
    	
58
    	
 
    	
62
    	
 
    	
65
    	
 
    	
68
    	
 
    	
71
    	
 
    	
72
    	
 
    	
73
    	
 
    	
74
    	
 
    	
74
    	
 
    	
75
    	
 
    	
75
    	
 
    	
75
    	
 
    	
74
    	
 
    	
74
    	
 
    	
73
    	
 
    	
73
    	
 
    	
68
    	
 
    	
62
    	
 
    	
1603
    	
 
    
	
AUG
    	
 
    	
58
    	
 
    	
56
    	
 
    	
56
    	
 
    	
55
    	
 
    	
55
    	
 
    	
56
    	
 
    	
59
    	
 
    	
62
    	
 
    	
65
    	
 
    	
68
    	
 
    	
69
    	
 
    	
71
    	
 
    	
71
    	
 
    	
72
    	
 
    	
73
    	
 
    	
74
    	
 
    	
74
    	
 
    	
74
    	
 
    	
74
    	
 
    	
72
    	
 
    	
74
    	
 
    	
71
    	
 
    	
65
    	
 
    	
61
    	
 
    	
1585
    	
 
    
	
SEP
    	
 
    	
46
    	
 
    	
45
    	
 
    	
44
    	
 
    	
44
    	
 
    	
44
    	
 
    	
47
    	
 
    	
52
    	
 
    	
53
    	
 
    	
55
    	
 
    	
56
    	
 
    	
56
    	
 
    	
57
    	
 
    	
57
    	
 
    	
57
    	
 
    	
58
    	
 
    	
58
    	
 
    	
58
    	
 
    	
59
    	
 
    	
59
    	
 
    	
62
    	
 
    	
62
    	
 
    	
59
    	
 
    	
53
    	
 
    	
48
    	
 
    	
1289
    	
 
    
	
OCT
    	
 
    	
49
    	
 
    	
48
    	
 
    	
47
    	
 
    	
47
    	
 
    	
49
    	
 
    	
52
    	
 
    	
58
    	
 
    	
60
    	
 
    	
60
    	
 
    	
60
    	
 
    	
59
    	
 
    	
59
    	
 
    	
58
    	
 
    	
58
    	
 
    	
57
    	
 
    	
57
    	
 
    	
58
    	
 
    	
59
    	
 
    	
62
    	
 
    	
65
    	
 
    	
63
    	
 
    	
60
    	
 
    	
56
    	
 
    	
51
    	
 
    	
1352
    	
 
    
	
NOV
    	
 
    	
57
    	
 
    	
56
    	
 
    	
56
    	
 
    	
56
    	
 
    	
57
    	
 
    	
61
    	
 
    	
66
    	
 
    	
68
    	
 
    	
67
    	
 
    	
67
    	
 
    	
65
    	
 
    	
65
    	
 
    	
63
    	
 
    	
62
    	
 
    	
62
    	
 
    	
62
    	
 
    	
65
    	
 
    	
73
    	
 
    	
74
    	
 
    	
73
    	
 
    	
71
    	
 
    	
68
    	
 
    	
64
    	
 
    	
59
    	
 
    	
1537
    	
 
    
	
DEC
    	
 
    	
58
    	
 
    	
56
    	
 
    	
56
    	
 
    	
56
    	
 
    	
57
    	
 
    	
60
    	
 
    	
65
    	
 
    	
68
    	
 
    	
67
    	
 
    	
67
    	
 
    	
65
    	
 
    	
64
    	
 
    	
62
    	
 
    	
61
    	
 
    	
60
    	
 
    	
61
    	
 
    	
65
    	
 
    	
74
    	
 
    	
75
    	
 
    	
74
    	
 
    	
73
    	
 
    	
71
    	
 
    	
65
    	
 
    	
60
    	
 
    	
1540
    	
 
    

 

11

 

AMENDMENT TO

WHOLESALE POWER CONTRACT

BY AND BETWEEN

BASIN ELECTRIC POWER COOPERATIVE

AND

TRI-STATE GENERATION AND TRANSMISSION ASSOCIATION, INC.

 

This Amendment to Wholesale Power Contract is made as of this 12th day of December, 2006, by and between Basin Electric Power Cooperative, 1717 East Interstate Avenue, Bismarck, North Dakota 58501 (Seller), a North Dakota electric cooperative corporation, and Tri-State Generation and Transmission Association, Inc., (Member), a Colorado non-profit cooperative corporation whose principal place of business is located in or near Denver, Colorado.

 

WITNESSETH:

 

WHEREAS, Seller and Member entered into a certain Wholesale Power Contract dated as of August 12, 1964, as amended (Wholesale Contract); and

 

WHEREAS, Seller and Member are entering into this Amendment to extend the term of their Wholesale Contract;

 

NOW THEREFORE, in consideration of the mutual undertakings herein contained, the parties hereby agree as follows:

 

I.                Section 10 of the Wholesale Contract as amended by Amendment Number 3 to Wholesale Power Contract dated July 2002, Section 3, is hereby amended by deleting the date “December 31, 2040”, and substituting the date “December 31, 2050”.

II.           This agreement is subject to the approval of the Administrator of the Rural Utilities Services.

 

Executed as of the day and year first above written.

 

1

 

	
 
    	
 
    	
BASIN   ELECTRIC POWER COOPERATIVE
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Wayne   L. Child
    
	
ATTEST:
    	
 
    	
Its:   
    	
President
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
/S/Kermit   Pearson
    	
 
    	
 
    	
 
    
	
Kermit   Pearson
    	
 
    	
 
    	
 
    
	
Secretary
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
TRI-STATE   GENERATION & TRANSMISSION
    
	
 
    	
 
    	
ASSOCIATION, INC.
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
By:
    	
/s/Harold   “Hub” Thompson
    
	
ATTEST:
    	
 
    	
Its:   
    	
President
    
	
 
    	
 
    	
 
    	
 
    
	
 
    	
 
    	
 
    	
 
    
	
/s/Wayne   L. Child
    	
 
    	
 
    	
 
    
	
Wayne   L. Child
    	
 
    	
 
    	
 
    
	
Assistant   Secretary
    	
 
    	
 
    	
 
    

 

2

Source: [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00243-of-00352.parquet"}, [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00243-of-00352.parquet"}]]