Document:

Exhibit 10.2

                                AMENDMENT TO THE

                            POWER PURCHASE AGREEMENT

                                     BETWEEN

                           BYRON POWER PARTNERS, L.P.

                                       AND

                        PACIFIC GAS AND ELECTRIC COMPANY

                              (PG&E LOG NO. 16C047)

     THIS AMENDMENT ("Amendment") is by and between PACIFIC GAS AND ELECTRIC
COMPANY ("PG&E"), a California corporation and Byron Power Partners, L.P., a
California limited partnership ("Seller"). PG&E and Seller are sometimes
referred to herein individually as "Party" and collectively as the "Parties"

                                    RECITALS

     A. On April 15, 1985, Seller (or Seller's predecessor, as applicable) and
entered into a Power Purchase Agreement, (as amended, "the PPA") pursuant to
which PG&E purchases electric power from Seller and Seller sells electric power
to PG&E.

     B. On April 6, 2001, PG&E filed voluntary petition under chapter 11 of the
United States Bankruptcy Code in the San Francisco Division of the United States
Bankruptcy Court for the Northern District of California (the "Bankruptcy
Court") (In re Pacific Gas and Electric Company, Banks. Case No. 01-03923).

     C. On June 14, 2001, the Commission issued D.01-06-015, which approved as
reasonable certain non-standard PPA price modifications.

     D. Seller and PG&E now desire to enter into the PPA price modification set
forth below. Seller has advised PG&E that Seller is unable to enter into the
PPA price modification unless the Bankruptcy Court has approved this Amendment
and Seller is provided a limited option to terminate this Amendment following
Bankruptcy Court approval if Seller is unable to

                                     1 of 3

<PAGE>

Arrange for fuel purchases to accommodate the price modification contemplated
under this Amendment.

                                    AMENDMENT

     In consideration of the mutual promises and covenants contained herein,
PG&E and Seller agree to as follows:

     1. INTERIM ENERGY PRICE

     Unless otherwise set fourth in the PPA, for the period commencing with the
date on which this Amendment has been executed by the Parties and ending upon
the commencement of the Fixed Rate Period, as defined in Section 2 below, the
price for energy delivered, if any, to PG&E by Seller shall be determined
pursuant to the PPA, without reference to this Amendment.

     2. FIXED ENERGY PRICE

     Commencing with this date that is the earlier of, August 1, 2001, August
16, 2001 or September 1, 2001 following approval of the Bankruptcy Court as
specified in Section 4 below (hereafter, the "Bankruptcy Court Approval Date")
and ending on July 15, 2006 (this period referred to hereafter as the "Fixed
Rate Period"), Seller elects to replace the energy price term specified in the
PPA (PG&E's "full short-run avoided costs" or "full short-run avoided operating
costs" as the case may be) with the applicable energy prices as specified in
Attachment A. No provision of the PPA other than the energy price term is or
shall be deemed to be modified, amended, waived or otherwise affected by this
Amendment. The parties agree to reasonably cooperate and contest any challenge
in any Commission proceeding that seeks to alter or modify the energy pricing
terms set fourth in Attachment A, including, but not limited to any challenge to
the reasonableness of PG&E having entered into this Amendment.

                                    2 of 3
<PAGE>

     3. SELLER'S OPTION PERIOD

     For a fifteen-day period following the Bankruptcy Court Approval Date,
Seller shall have the sole right to terminate this Amendment. Upon termination
of this Amendment pursuant to this section 3, this Amendment shall be deemed a
nullity.

     4. EFFECTIVENESS

     This Amendment shall not become effective unless and until it has been
approved by the Bankruptcy Court. If the Bankruptcy Court has not approved this
Amendment by August 31, 2001, this Amendment shall be deemed a nullity.

     5. SIGNATURES

     IN WITNESS WHEREOF, Seller and PG&E have caused this Amendment to be
executed by their authorized representatives.

PACIFIC GAS AND ELECTRIC COMPANY
 a California corporation

By:   [illegible]
      -------------------------

Title: [illegible]
      -------------------------

Date: 7/14/01
      -------------------------

BYRON POWER PARTNERS, L.P.
a California limited partnership

By:   [illegible]
      -------------------------

Title: Ex VP & COO
      -------------------------

Date: 7/13/01
      -------------------------

                       3 of 3
<PAGE>

Pacific Gas and Electric Company

June 1, 1993

[LOGO OMITTED]    ALTAMONT COGENERATION CORPORATION
                  Attn: Bob Pollock
                  c/o Wankesha-Pearce
                  12320 South Main
                  HOUSTON, TX 77235-5068

                  Dear Sir/Madam:

                  This is to notify you of a change of address for Article 9,
                  "Notices", of the Power Purchase Agreement (PPA) between PG&E
                  and Altamont Cogeneration Corporation. Please direct all
                  future written notices to:

                                   Mr. Richard A. Lavne
                                   Director, Power Finance Department, B13D
                                   Pacific Gas and Electric Company
                                   77 Beale Street, Room 1311
                                   P.O. Box 770000 San
                                   Francisco, CA 94177

                  The address in the PPA relating to insurance matters has also
                  changed. All insurance certificates, endorsements.
                  cancellations, terminations, alterations, and material changes
                  of such insurance must be issued and submitted to the
                  following:

                                   Pacific Gas and Electric Company
                                   Power Contracts Department - B23C
                                   Attn: Insurance Coordinator
                                   P.O. Box 770000, Room 2354
                                   San Francisco, CA 94177

                  CPUC Decision 93-04-001 dated April 7, 1993, adopted the
                  Division of Ratepayer Advocate's recommendation for modifying
                  the reporting requirements applicable to the quarterly report
                  of negative avoided cost or hydro spill. The above decision
                  ordered that: Decision (D) 82-01-103, Ordering Paragraph 17,
                  is modified to read in full as follows:

                        "Each utility shall promptly file a report for any
                        quarter in which a negative avoided cost or hydro
                        spill condition occurs."

                  Please inform all parties in your organization of the above
                  information. If you have any questions please call me at (415)
                  973-4966.

                  Sincerely,

                  /s/ Dave Harrison
                  Dave Harrison
                  Power System Analyst
                  (415)973-4966

<PAGE>

                        PACIFIC GAS AND ELECTRIC COMPANY

                               STANDARD OFFER #4

                            POWER PURCHASE AGREEMENT

                                      FOR

                         LONG-TERM ENERGY AND CAPACITY

     Seller: Fayette Manufacturing Corporation

     Location: Altamont Pass

     Nameplate Rating: 6,500 kW

     Firm Capacity: 5,700 kW

     Energy Source: Natural Gas

                                    MAY 1984

                                                                          S.O #4
                                                                     May 7, 1984

                                       1
<PAGE>

                               STANDARD OFFER #4:
                          LONG-TERM ENERGY AND CAPACITY
                            POWER PURCHASE AGREEMENT

                                    CONTENTS

     Article                                                                Page
     -------                                                                ----

     1         QUALIFYING STATUS                                             3

     2         COMMITMENT OF PARTIES                                         4

     3         PURCHASE OF POWER                                             5

     4         ENERGY PRICE                                                  6

     5         CAPACITY ELECTION AND CAPACITY PRICE                         10

     6         LOSS ADJUSTMENT FACTORS                                      11

     7         CURTAILMENT                                                  11

     8         RETROACTIVE APPLICATION OF CPUC ORDERS                       12

     9         NOTICES                                                      12

     10        DESIGNATED SWITCHING CENTER                                  13

     11        TERMS AND CONDITIONS                                         13

     12        TERM OF AGREEMENT                                            14

     Appendix A:       GENERAL TERMS AND CONDITIONS

     Appendix B:        ENERGY PAYMENT OPTIONS

     Appendix C:        CURTAILMENT OPTIONS

     Appendix D:        AS-DELIVERED CAPACITY

     Appendix E:        FIRM CAPACITY

     Appendix F:        INTERCONNECTION

                                       2                                  S.O #4
                                                                     May 7, 1984
<PAGE>

                          LONG-TERM ENERGY AND CAPACITY

                            POWER PURCHASE AGREEMENT

                                     BETWEEN

                        FAYETTE MANUFACTURING CORPORATION

                                       AND

                        PACIFIC GAS AND ELECTRIC COMPANY

          FAYETTE MANUFACTURING CORPORATION, a Pennsylvania corporation
     ("Seller"), and PACIFIC GAS AND ELECTRIC COMPANY ("PGandE"), referred to
     collectively as "Parties" and individually as "Party", agree as follows:

                          ARTICLE 1 QUALIFYING STATUS

          Seller warrants that, at the date of first power deliveries from
     Seller's Facility' and during the term of agreement, its Facility shall
     meet the qualifying facility requirements established as of the effective
     date of this Agreement by the Federal Energy Regulatory Commission's rules
     (18 Code of Federal Regulations 292) implementing the Public Utility
     Regulatory Policies Act of 1978 (16 U.S.C.A. 796, at seq.).

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

     1    Underlining identifies those terms which are defined in Section S-1 of
          Appendix A.

                                       3                                  S.O #4
                                                                     May 7, 1984
<PAGE>

                         ARTICLE 2 COMMITMENT OF PARTIES

          The prices to be paid Seller for energy and/or capacity delivered
     pursuant to this Agreement have wholly or partly been fixed at the time of
     execution. Actual avoided costs at, the time of energy and/or capacity
     deliveries may be substantially above or below the prices fixed in this
     Agreement. Therefore, the Parties expressly commit to the prices fixed in
     this Agreement for the applicable period of performance and shall not seek
     to or have a right to renegotiate such prices for any reason. As part of
     its consideration for the benefit of fixing part or all of the energy
     and/or capacity prices under this Agreement, Seller waives any and all
     rights to judicial or other relief from its obligations and/or prices set
     forth in Appendices B, D, and E, or modification of any other term or
     provision for any reasons whatsoever.

          This Agreement contains certain provisions which set forth methods of
     calculating damages to be paid to PGandE in the event Seller fails to
     fulfill certain performance obligations. The inclusion of such provisions
     is not intended to create any express or implied right in Seller to
     terminate this Agreement prior to the expiration of the term of agreement.
     Termination of this Agreement by Seller prior to its expiration date shall
     constitute a breach of this Agreement and the damages expressly set forth
     in this

                                       4                                  S.O #4
                                                                     May 7, 1984
<PAGE>

     Agreement shall not constitute PGandE's sole remedy for such breach.

                           ARTICLE 3 PURCHASE OF POWER

          (a) Seller shall sell and deliver and PGandE shall purchase and accept
     delivery of capacity and energy at the voltage level of 115 kW.

          (b) Seller shall provide capacity and energy from its 6,500 kW
     Facility located in the Altamont Pass.

          (c) The scheduled operation date of the Facility is February 1, 1987.
     At the end of each calendar quarter Seller shall give written notice to
     PGandE of any change in the scheduled operation date.

          (d) To avoid exceeding the physical limitations of the interconnection
     facilities, Seller shall limit the Facility's actual rate of delivery into
     the PGandE system to 6,500 kW.

     (e) The primary energy source for the Facility is natural gas.

                                       5                                  S.O #4
                                                                     May 7, 1984
<PAGE>

          (f) If Seller does not begin construction of its Facility by November
     30, 1986, PGandE may reallocate the existing capacity on PGandE's
     transmission and/or distribution system which would have been used to
     accommodate Seller's power deliveries to other uses. In the event of such
     reallocation, Seller shall pay PGandE for the cost of any upgrades or
     additions to PGandE's system necessary to accommodate the output from the
     Facility. Such additional facilities shall be installed, owned and
     maintained in accordance with the applicable PGandE tariff.

     (g) The transformer loss adjustment factor is ____________1

                             ARTICLE 4 ENERGY PRICE

          PGandE shall pay Seller for its surplus energy output2 under the
     energy payment option checked below3:

     X     Energy Payment Option 1 - Forecasted Energy Prices
     -

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

     1    If Seller chooses to have meters placed on Seller's side of the
          transformer, an estimated transformer loss adjustment factor of 2
          percent, unless the Parties agree otherwise, will be applied. This
          estimated transformer loss figure will be adjusted to a measurement of
          actual transformer losses performed at Seller's request and expense.
          In addition, a line loss percentage to the low side meter will be
          determined by the Parties and added to the transformer loss adjustment
          factor.

     2    Insert either "net energy output" or "surplus energy output" to show
          the energy sale option selected by Seller.

     3    Energy Payment option 2 is not available to oil or gas-fired
          cogenerators.

                                       6                                  S.O #4
                                                                     May 7, 1984
<PAGE>

          During the fixed price period, Seller shall be paid for energy
     delivered at prices equal to 01 percent of the prices set forth in Table
     B-1, Appendix B, plus 1002 percent of PGandE's full short-run avoided
     operating costs.

          For the remaining years of the term of agreement, Seller shall be paid
     for energy delivered at prices equal to PCandE's full short-run avoided
     operating costs.

          If Seller's Facility is not an oil or gas-fired cogeneration facility,
     Seller may convert from Energy Payment Option 1 to Energy Payment option 2
     and be subject to the conditions therein, provided that Seller shall not
     change the percentage of energy prices to be based on PGandE's full
     short-run avoided operating costs. Such conversion must be made at least 90
     days prior to the date of initial energy deliveries and must be made by
     written notice in accordance with Section A-17, Appendix A.

     _____  Energy Payment Option 2 - Levelized Energy Prices

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

     (1)  Insert either 0, 20, 40, 60, 80, or 100, at Seller's option. If
          Seller's Facility is an oil or gas-fired cogeneration facility, either
          0 or 20 must be inserted.

     (2)  Insert the difference between 100 and the percentage selected under
          footnote 1 above.

                                       7                                  S.O #4
                                                                     May 7, 1984
<PAGE>

          During the fixed price period, Seller shall be paid for energy
     delivered at prices equal to ________ 1 percent of the levelized energy
     prices set forth in Table B-2, Appendix B for the year in which energy
     deliveries begin and term of agreement, plus ___________2 percent of
     PGandE's full short-run avoided operating costs. During the fixed price
     period, Seller shall be subject to the conditions and terms set forth in
     Appendix B, Energy Payment Option 2.

          For the remaining years of the term of agreement, Seller shall be paid
     for energy delivered at prices equal to PGandE's full short-run avoided
     operating costs.

     Seller may convert from Energy Payment Option 2 to Energy Payment Option 1,
provided that Seller shall not change the percentage of energy prices to be
based on PGandE's full short-run avoided operating costs. Such conversion must
be made at least 90 days prior to the date of initial energy deliveries and must
be made by written notice in accordance with Section A-17, Appendix A.

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

     1    Insert either 20, 40, 60, 80, or 100, at Seller's option.

     2    Insert the difference between 100 and the percentage selected under
          footnote 1 above.

                                       8                                  S.O #4
                                                                     May 7, 1984
<PAGE>

     _____  Energy Payment Option 3 - Incremental Energy Rate

          Beginning with the date of initial energy deliveries and continuing
     until ______________1, seller shall be paid monthly for energy delivered at
     prices equal to PGandE's full short-run avoided operating costs, provided
     that adjustments shall be made annually to the extent set forth in Appendix
     B, Energy Payment Option 3.

          The incremental Energy Rate Band widths specified by Seller in Table I
     below shall be used in determining the annual adjustment, if any.

                                     Table I
                                     -------

     Year                 Incremental Energy Rate Band Widths
     ----                 -----------------------------------
                          (must be multiples of 100 or zero)

     1984                          -------------
     1985                          -------------
     1986                          -------------
     1987                          -------------
     1988                          -------------
     1989                          -------------
     1990                          -------------
     1991                          -------------
     1992                          -------------
     1993                          -------------
     1994                          -------------
     1995                          -------------
     1996                          -------------
     1997                          -------------
     1998                          -------------

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

     1    Specified by Seller must be December 31, 1998 or prior.

                                       9
                                                                          S.O #4
                                                                     May 7, 1984
<PAGE>

          After __________, Seller shall be paid to: energy delivered at prices
     equal to PGandE's full short-run, avoided operating costs.

                 ARTICLE 5 CAPACITY ELECTION AND CAPACITY PRICE

          Seller may elect to deliver either firm capacity or as-delivered
     capacity, and Seller's election is indicated below. PGandE's prices fox
     firm capacity and as-delivered capacity die derived from PGandE's full
     avoided costs as approved by the CPUC.

     X   Firm capacity - 5,700 kW for 30 years from the firm capacity
         availability date with payment determined in accordance with
         Appendix E. Except for hydro- electric facilities, PGandE shall
         pay Seller for capacity delivered in excess of firm capacity on
         an as-delivered capacity basis in accordance with As-Delivered
         Capacity Payment Option 1 set forth in Appendix D.

                                       OR

     __  As-delivered capacity with payment determined in accordance with
         As-Delivered Capacity Payment Option set forth in Appendix D.

                                       10                                 S.O #4
                                                                     May 7, 1984
<PAGE>

                        ARTICLE 6 LOSS ADJUSTMENT FACTORS

          Capacity Loss Adjustment Factors shall be as shown in Appendix D and
     Appendix E, dependent upon Seller's capacity election set forth in Article
     5 of this Agreement.

          Energy Loss Adjustment Factors shall be considered as unity for all
     energy payments related to Energy Payment Options I and 2 set forth in
     Appendix B for the entire fixed price period of this Agreement, except for
     the percentage of' payments that Seller elected in Article 4 to have
     calculated based on PGandE's full short-run avoided operating costs. Energy
     Loss Adjustment Factors for all payments related to PGandE's full short-run
     avoided operating costs are subject to CPUC rulings for the entire term of
     agreement.

                              ARTICLE 7 CURTAILMENT

          Seller has two options regarding possible curtailment by PGandE of
     Seller's deliveries, and Seller's selection is indicated below:

     X   Curtailment Option A - Hydro Spill and Negative Avoided Cost
    --
    __   Curtailment Option B - Adjusted Price Period

         The two options are described in Appendix C.

                                       11                                 S.O #4
                                                                     May 7, 1984
<PAGE>

                ARTICLE 8 RETROACTIVE APPLICATION OF CPUC ORDERS

          Pursuant to Ordering Paragraph l (f) of CPUC Decision No. 83-09-054
     (September 7, 1983), after the effective date of the CPUC's Application
     B2-03-26 decision relating to line loss factors, Seller has the option to
     retain the relevant terms of this Agreement or have the results of that
     decision incorporated into this Agreement. To retain the terms herein,
     Seller shall provide written notice to PGandE within 30 days after the
     effective date of the relevant CPUC decision on Application 82-03-26.
     Failure to provide such notice will result in the amendment of this
     Agreement to comply with that decision.

          As soon as practicable following the issuance of a decision in
     Application 82-03-26, PGandE shall notify Seller of the effective date
     thereof and its results.

                                ARTICLE 9 NOTICES

          All written notices shall be directed as follows:

          To PGandE:     Pacific Gas and Electric Company
                         Attention: Vice President -
                         Electric Operations
                         77 Beale Street
                         San Francisco, CA 94106

                                       12                                 S.O #4
                                                                     May 7, 1984
<PAGE>

          To Seller:     Fayette Manufacturing Corporation
                         Attention: Arthur C. Beard
                         P.O. Box 1149
                         Tracy, CA 95376

                     ARTICLE 10 DESIGNATED SWITCHING CENTER

          The designated PGandE switching center shall be, unless changed by
     PGandE:

                         Tesla Substation
                         Patterson Pass Road
                         Tracy, CA 95376
                         (209)835-6391

                         ARTICLE 11 TERMS AND CONDITIONS

          This Agreement includes the following appendices which are attached
     and incorporated by reference:

     Appendix A -   GENERAL TERMS AND CONDITIONS

     Appendix B -   ENERGY PAYMENT OPTIONS

     Appendix C -   CURTAILMENT OPTIONS

     Appendix D -   AS-DELIVERED CAPACITY

     Appendix E -   FIRM CAPACITY

     Appendix F -   INTERCONNECTION

                                       13                                 S.O #4
                                                                     May 7, 1984
<PAGE>

                          Article 12 TERM OF AGREEMENT

          This Agreement shall be binding upon execution and remain in effect
     thereafter for 30 years' from the firm capacity availability date2;
     provided, however, that it shall terminate if energy deliveries do not
     start within five years of the execution date.

          IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to
     be executed by their duly authorized representatives- and it is effective
     as of the last date set forth below.

     FAYETTE MANUFACTURING CORPORATION         PACIFIC GAS AND ELECTRIC COMPANY

     BY:/s/ JOHN S. PRESTON                    BY: /s/ NOLAN H. DAINES
        -------------------                        -------------------
            JOHN S. PRESTON                            NOLAN H. DIANES

                                                      Vice President -
     TITLE: General Counsel                    TITLE: Planning and Research

     DATE SIGNED: April 12, 1985               DATE SIGNED: 4/15/85
                  --------------                            -------

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

          1    The minimum contract term is 15 years and the maximum contract
               term is 30 years.

          2    Insert "firm capacity availability date" if Seller has elected to
               deliver firm capacity or "date of initial energy deliveries" if
               Seller has elected to deliver as-delivered capacity.

                                       14                                 S.O #4
                                                                     May 7, 1984
<PAGE>

                                   APPENDIX A

                          GENERAL TERMS AND CONDITIONS

                                    CONTENTS

     Section                                                   Page
     -------                                                   -----

       A-1          DEFINITIONS                                  A-2

       A-2          CONSTRUCTION                                 A-7

       A-3          OPERATION                                    A-11

       A-4          PAYMENT                                      A-14

       A-5          ADJUSTMENTS OF PAYMENTS                      A-15

       A-6          ACCESS TO RECORDS AND PGandE DATA            A-15

       A-7          INTERRUPTION OF DELIVERIES                   A-16

       A-8          FORCE MAJEURE                                A-16

       A-9          INDEMNITY                                    A-17

       A-10         LIABILITY; DEDICATION                        A-18

       A-11         SEVERAL OBLIGATIONS                          A-19

       A-12         NON-WAIVER                                   A-19

       A-13         ASSIGNMENT                                   A-19

       A-14         CAPTIONS                                     A-20

       A-15         CHOICE OF LAWS                               A-20

       A-16         GOVERNMENTAL JURISDICTION AND                A-20
                    AUTHORIZATION

       A-17         NOTICES                                      A-21

       A-18         INSURANCE                                    A-21

                                       A-1
<PAGE>

                                   APPENDIX A

                          GENERAL TERMS AND CONDITIONS

     A-1 DEFINITIONS

          Whenever used in this Agreement, appendices, and attachments hereto,
     the following terms shall have the following meanings:

          Adjusted firm capacity price - The $/kW-year purchase price for firm
     capacity from Table E-2, Appendix E for the period of Seller's actual
     performance.

          As-delivered capacity - Capacity delivered to PGandE in excess of firm
     capacity or in lieu of a firm capacity commitment.

          CPUC - The Public Utilities Commission of the State of California.

          Current firm capacity price - The $/kW-year capacity price from
     PGandE's firm capacity price schedule effective at the time PGandE Berates
     the firm capacity pursuant to Section E-4(b), Appendix E or Seller
     terminates performance under this Agreement, for a term equal to the period
     from the date of deration or termination to the end of the term of
     agreement.

                                      A-2
<PAGE>

          Designated PGandE switching center - That switching center or other
     PGandE installation identified in Article 10.

          Facility - That generation apparatus described in Article 3 and all
     associated equipment owned, maintained, and operated by Seller.

          Firm capacity - That capacity, if any, identified as firm in Article 5
     except as otherwise changed as provided herein.

          Firm capacity availability date - The day following the day during
     which all features and equipment of the Facility are demonstrated to
     PGandE's satisfaction to be capable of operating simultaneously to deliver
     firm capacity continuously into PGandE's system as provided in this
     Agreement.

          Firm capacity price - The price for firm capacity applicable for the
     firm capacity availability date and the number of years of firm capacity
     delivery from the firm capacity price schedule, Table E-2, Appendix E.

                                      A-3
<PAGE>

          Firm capacity price schedule - The periodically published schedule of
     the $/kW-year prices that PGandE offers to pay for firm capacity. See Table
     E-2, Appendix E.

          Fixed price Period - The period during which forecasted or levelized
     energy prices, and/or forecasted as-delivered Capacity prices, are in
     effect; defined as the first five years of the term of agreement if the
     term of agreement is 15 or 16 years; the first six years of the term of
     agreement if the term of agreement is 17, 18, or 19 years; or the first ten
     years of the term of agreement if the term of agreement is anywhere from 20
     through 30 years.

          Forced outage - Any outage resulting from a design defect, inadequate
     construction, operator error or a breakdown of the mechanical or electrical
     equipment that fully or partially curtails the electrical output of the
     Facility.

          Full short-run avoided operating costs - CPUC-approved costs which are
     the basis of PGandE's published energy prices. PGandE's current energy
     price calculation is shown in Table B-5, Appendix B. PGandE's published
     off-peak hours' prices shall be adjusted, as appropriate, if Seller has
     selected Curtailment Option B.

                                      A-4
<PAGE>

          Interconnection facilities - All means required and apparatus
     installed to interconnect and deliver power from the Facility to the PGandE
     system including, but not limited, to, connection, transformation,
     switching, metering, communications, and safety equipment, such as
     equipment required to protect (1) the PGandE system and its customers from
     faults occurring at the Facility, and (2) the Facility from faults
     occurring on the PGandE system or on the systems of others to which the
     PGandE system is directly or indirectly connected. Interconnection
     facilities also include any necessary additions and reinforcements by
     PGandE to the PGandE system required as a result of the interconnection of
     the Facility to the PGandE system.

          Net energy output - The Facility's gross output in kilowatt-hours less
     station use and transformation and transmission losses to the point of
     delivery into the PGandE system. Where PGandE agrees that it is impractical
     to connect the station use on the generator side of the power purchase
     meter, PGandE may, at its option, apply a station load adjustment.

          Prudent electrical practices - Those practices, methods, and
     equipment, as changed from time to time, that are commonly used in prudent
     electrical engineering and operations to design and operate electric
     equipment lawfully and with safety, dependability, efficiency, and economy.

                                      A-5
<PAGE>

          Scheduled operation date - The day specified in Article 3 (c) when the
     Facility is, by Seller's estimate, expected to produce energy that will be
     available for delivery to PGandE.

          Special facilities - Those additions and reinforcements to the PGandE
     system which are needed to accommodate the maximum delivery of energy and
     capacity from the Facility as provided in this Agreement and those parts of
     the interconnection facilities which are owned and maintained by PGandE at
     Seller's request, including metering and data processing equipment. All
     special facilities shall be owned, operated, and maintained pursuant to
     PGandE's electric Rule No. 21, which is attached hereto.

          Station use - Energy used to operate the Facility's auxiliary
     equipment. The auxiliary equipment includes, but is not limited to, forced
     and induced draft fans, cooling towers, boiler feed pumps, lubricating oil
     systems, plant lighting, fuel handling systems, control systems, and sump
     pumps.

          Surplus energy output - The Facility's gross output, in
     kilowatt-hours, less station use, and any other use by Seller, and
     transformation and transmission losses to the point of delivery into the
     PGandE system.

                                      A-6
<PAGE>

          Term of agreement - The number of years this Agreement will remain in
     effect as provided in Article 12.

          Voltage level - The voltage at which the Facility interconnects with
     the PGandE system, measured at the point of delivery.

     A-2  CONSTRUCTION

     A-2.1  Land Rights

          Seller hereby grants to PGandE all necessary rights of way and
     easements, including adequate and continuing access rights on property of
     Seller, to install, operate, maintain, replace, and remove the special
     facilities. Seller agrees to execute such other grants, deeds, or documents
     as PGandE may require to enable it to record such rights :of way and
     easements. If any part of PGandE's equipment is to be installed on property
     owned by other than Seller, Seller shall, at its own cost and expense,
     obtain from the owners thereof all necessary rights of way and easements,
     in a form satisfactory to PGandE, for the construction, operation,
     maintenance, and replacement of PGandE's equipment upon such property. If
     Seller is unable to obtain such rights of way and easements, Seller shall

                                      A-7
<PAGE>

     reimburse PGandE for all costs incurred by PGandE in obtaining them. PGandE
     shall at all times have the right of ingress to and egress from the
     Facility at all reasonable hours for any purposes reasonably connected with
     this Agreement or the exercise of any and all rights secured to PGandE by
     law or its tariff schedules.

      A-2.2 Design, Construction, Ownership, and Maintenance

          (a) Seller shall design, construct, install, own, operate, and
     maintain all interconnection facilities, except special facilities, to the
     point of interconnection with the PGandE system as required for PGandE to
     receive capacity and energy from the Facility. The Facility and
     interconnection facilities shall meet all requirements of applicable codes
     and all standards of prudent electrical practices and shall be maintained
     in a safe and prudent manner. A description of the interconnection
     facilities for which Seller is solely responsible is set forth in Appendix
     F, or if the interconnection requirements have not yet been determined at
     the time of the execution of this Agreement, the description of such
     facilities will be appended to this Agreement at the time such
     determination is made.

          (b) Seller shall submit to PGandE the design and all specifications
     for the interconnection facilities (except special facilities) and, at
     PGandE's option, the Facility, for review and written acceptance prior to

                                      A-8
<PAGE>

          their release for construction purposes. PGandE shall notify Seller in
     writing of the outcome of PGandE's review of the design and specifications
     for Seller's interconnection facilities (and the Facility, if requested)
     within 30 days of the receipt of the design and all of the specifications
     for the interconnection facilities (and the Facility, if requested). Any
     flaws perceived by PGandE in the design and specifications for the
     interconnection facilities (and the Facility, if requested) will be
     described in PGandE's written notification. PGandE's review and acceptance
     of the design and specifications shall not be construed as confirming or
     endorsing the design and specifications or as warranting their safety,
     durability, or reliability. PGandE shall not, by reason of such review or
     lack of review, be responsible for strength, details of design, adequacy,
     or capacity of equipment built pursuant to such design and specifications,
     nor shall PGandE's acceptance be deemed to be an endorsement of any of such
     equipment. Seller shall change the interconnection facilities as may be
     reasonably required by PGandE to meet changing requirements of the PGandE
     system.

          (c) In the event it is necessary for PGandE to install interconnection
     facilities for the purposes of this Agreement, they shall be installed as
     special facilities.

                                      A-9
<PAGE>

          (d) Upon the request of Seller, PGandE shall provide a binding
     estimate for the installation of interconnection facilities by PGandE.

     A-2.3  Meter Installation

          (a) PGandE shall specify, provide, install, own, operate, and maintain
     as special facilities all metering and data processing equipment for the
     registration and recording of energy and other related parameters which are
     required for the reporting of data to PGandE and for computing the payment
     due Seller from PGandE.

          (b) Seller shall provide, construct, install, own, and maintain at
     Seller's expense all that is required to accommodate the metering and data
     processing equipment, such as, but not limited to, metal-clad switchgear,
     switchboards, cubicles, metering panels, enclosures, conduits, rack
     structures, and equipment mounting pads.

          (c) PGandE shall permit meters to be fixed on PGandE's side of the
     transformer. If meters are placed on PGandE's side of the transformer,
     service will be provided at the available primary voltage and no
     transformer loss adjustment will be made. If Seller chooses to have meters
     placed on Seller's side of the transformer, an estimated transformer loss
     adjustment factor of 2 percent, unless the Parties agree otherwise, will be
     applied.

                                      A-10
<PAGE>

     A-3  OPERATION

     A-3.1  Inspection and Approval

          Seller shall not operate the Facility in parallel with PGandE's system
     until an authorized PGandE representative has inspected the interconnection
     facilities, and PGandE has given written approval to begin parallel
     operation. Seller shall notify PGandE of the Facility's start-up date at
     least 45 days prior to such date. PGandE shall inspect the interconnection
     facilities within 30 days of the receipt of such notice. If parallel
     operation is not authorized by PGandE, PGandE shall notify Seller in
     writing within five days after inspection of the reason authorization for
     parallel operation was withheld.

     A-3.2  Facility Operation and Maintenance

          Seller shall operate and maintain its Facility according to prudent
     electrical practices, applicable laws, orders, rules, and tariffs and
     shall provide such reactive power support as may be reasonably required by
     PGandE to maintain system voltage level and power factor. Seller shall
     operate the Facility at the power factors or voltage levels prescribed by
     PGandE's system dispatcher or designated- representative. If Seller fails
     to provide reactive power support, PGandE may do so at Seller's expense.

                                      A-11
<PAGE>

     A-3.3  Point of Delivery

          Seller shall deliver the energy at the point where Seller's electrical
     conductors (or those of Seller's agent) contact PGandE's system as it shall
     exist whenever the deliveries are being made or at such other point or
     points as the Parties may agree in writing. The initial point of delivery
     of Seller's power to the PGandE system is set forth in Appendix F.

     A-3.4  Operating Communications

          (a) Seller shall maintain operating communications with the designated
     PGandE switching center. The operating communications shall include, but
     not be limited to, system paralleling or separation, scheduled and
     unscheduled shutdowns, equipment clearances, levels of operating voltage or
     power factors and daily capacity and generation reports.

          (b) Seller shall keep a daily operations log for each generating unit
     which shall include information on unit availability, maintenance outages,
     circuit breaker trip operations requiring a manual reset, and any
     significant events related to the operation of the Facility.

          (c) if Seller makes deliveries greater than one megawatt, Seller shall
     measure and register on a graphic recording device power in kW and voltage
     in kV at a location within the Facility agreed to by both Parties.

                                      A-12
<PAGE>

          (d) If Seller makes deliveries greater than one and up to and
     including ten megawatts, Seller shall report to the designated PGandE
     switching center, twice a day at agreed upon times for the current day's
     operation, the hourly readings in kW of capacity delivered and the energy
     in kWh delivered since the last report.

          (e) If Seller makes deliveries of greater than ten megawatts, Seller
     shall telemeter the delivered capacity and energy information, including
     real power in kW, reactive power in kVAR, and energy in kWh to a switching
     center selected by PGandE. PGandE may also require Seller to telemeter
     transmission kW, kVAR, and kV data depending on the number of generators
     and transmission configuration. Seller shall provide and maintain the data
     circuits required for telemetering. When telemetering is inoperative,
     Seller shall report daily the capacity delivered each hour and the energy
     delivered each day to the designated PGandE switching center.

     A-3.5  Meter Testing and Inspection

          (a) All meters used to provide data for the computation of the
     payments due Seller from PGandE shall be sealed, and the seals shall be
     broken only by PGandE when the meters are to be inspected, tested, or
     adjusted.

                                      A-13
<PAGE>

          (b) PGandE shall inspect and test all meters upon their installation
     and annually thereafter. At Seller's request and expense, PGandE shall
     inspect or test a meter more frequently. PGandE shall give reasonable
     notice to Seller of the time when any inspection or test shall take place,
     and Seller may have representatives present at the test or inspection. If a
     meter is found to be inaccurate or defective, PGandE shall adjust, repair,
     or replace it at its expense in order to provide accurate metering.

     A-3.6  Adjustments to Meter Measurements

          If a meter fails to register, or if the measurement made by a meter
     during a test varies by more than two percent from the measurement made by
     the standard meter used in the test, an adjustment shall be made correcting
     all measurements made by the inaccurate meter for --(1) the actual period
     during which inaccurate measurements were made, if the period can be
     determined, or if not, (2) the period immediately preceding the test of the
     meter equal to one-half the time from the date of the last previous test of
     the meter, provided that the period covered by the correction shall not
     exceed six months.

     A-4  PAYMENT

          PGandE shall mail to Seller not later than 30 days after the end of
     each monthly billing period (1) a statement showing the energy and capacity

                                      A-14
<PAGE>

     delivered to PGandE during on-peak, partial-peak, and off-peak periods
     during the monthly billing period, (2) PGandE's computation of the amount
     due Seller, and (3) PGandE's check in payment of said amount. Except as
     provided in Section A-5, if within 30 days of receipt of the statement
     Seller does not make a report in writing to PGandE of an error, Seller
     shall be deemed to have waived any error in PGandE's statement,
     computation, and payment, and they shall be considered correct and
     complete.

     A-5  ADJUSTMENTS OF PAYMENTS

          (a) In the event adjustments to payments are required as a result of
     inaccurate meters, PGandE shall use the corrected measurements described
     in. Section A-3.6 to recompute the amount due from PGandE to Seller for the
     capacity and energy delivered under this Agreement during the period of
     inaccuracy.

          (b) The additional payment to Seller or refund to PGandE shall be made
     within 30 days of notification of the owing Party of the amount due.

     A-6  ACCESS TO RECORDS AND PGandE DATA

          Each Party, after giving reasonable written notice to the other Party,
     shall have the right of access to all metering and related records

                                      A-15
<PAGE>

     including operations logs of the Facility. Data filed by PGandE with the
     CPUC pursuant to CPUC orders governing the purchase of power from
     qualifying facilities shall be provided to Seller upon request; provided
     that Seller shall reimburse PGandE for the costs it incurs to respond to
     such request.

     A-7 INTERRUPTION OF DELIVERIES

          PGandE shall not be obligated to accept or pay for and may require
     Seller to interrupt or reduce deliveries of energy (1) when necessary in
     order to construct, install, maintain, repair, replace, remove,
     investigate, or inspect any of its equipment or any part of its system, or
     (2) if it determines that interruption or reduction is necessary because of
     PGandE system emergencies, forced outages, force majeure, or compliance
     with prudent electrical practices; provided that PGandE shall not interrupt
     deliveries pursuant to this section in order to take advantage, or make
     purchases, of less expensive energy elsewhere. Whenever possible, PGandE
     shall give Seller reasonable notice of the possibility that interruption or
     reduction of deliveries may be required.

     A-8  FORCE MAJEURE

          (a) The term force majeure as used herein means unforeseeable causes,
     other than forced outages, beyond the reasonable control of and without

                                      A-15
<PAGE>

     the fault or negligence of the Party claiming force majeure including,
     but not limited to, acts of God, labor disputes, sudden actions of the
     elements, actions by federal, state, and municipal agencies, and actions of
     legislative, judicial, or regulatory agencies which conflict with the terms
     of this Agreement.

          (b) If either Party because of force majeure is rendered wholly or
     partly unable to perform its obligations under this Agreement, that Party
     shall be excused from whatever performance is affected by the force majeure
     to the extent so affected provided that:

               (1) the non-performing Party, within two weeks after the
          occurrence of the force majeure, gives the other Party written notice
          describing the particulars of the occurrence,

               (2) the suspension of performance is of no greater scope and of
          no longer duration than is required by the force majeure,

               (3) the non-performing Party uses its best efforts to remedy its
          inability to perform (this subsection shall not require the settlement
          of any strike, walkout, lockout or other labor dispute on terms which,
          in the sole judgment of the Party involved in the dispute, are
          contrary to its interest. It is understood and agreed that the
          settlement of strikes, walkouts, lockouts or other labor disputes

                                      A-16
<PAGE>

          shall be at the sole discretion of the Party having the difficulty),

               (4) when the non-performing Party is able to resume performance
          of its obligations under this Agreement, that Party shall give the
          other Party written notice to that effect, and

               (5) capacity payments during such periods of force majeure on
          Seller's part shall be governed by Section E-2(c), Appendix E.

          (c) In the event a Party is unable to perform due to legislative,
     judicial, or regulatory agency action, this Agreement shall be renegotiated
     to comply with the legal change which caused the non-performance.

     A-9  INDEMNITY

          Each Party as indemnitor shall save harmless and indemnify the other
     Party and the directors, officers, and employees of such other Party
     against and from any and all loss and liability for injuries to persons
     including employees of either Party, and property damages including
     property of either Party resulting from or arising out of (1) the
     engineering, design, construction, maintenance, or operation of, or (2) the
     making of replacements, additions, or betterments to, the indemnitor's
     facilities. This indemnity and save harmless provision shall apply
     notwithstanding the active or passive negligence of the indemnitee. Neither

                                      A-17
<PAGE>

     Party shall be indemnified hereunder for its liability or loss resulting
     from its sole negligence or willful misconduct. The indemnitor shall, on
     the other Party's request, defend any suit asserting a -claim covered by
     this indemnity and shall pay all costs, including reasonable attorney fees,
     that may be incurred by the other Party in enforcing this indemnity.

     A-l0 LIABILITY; DEDICATION

          (a) Nothing in this Agreement shall create any duty to, any standard
     of care with reference to, or any liability to any person not a Party to
     it. Neither Party shall be liable to the other Party for consequential
     damages.

          (b) Each Party shall be responsible for protecting its facilities from
     possible damage by reason of electrical disturbances or faults caused by
     the operation, faulty operation, or noncooperation of the other Party's
     facilities, and' such other Party shall not be liable for any such damages,
     so caused.

          (c) No undertaking by one Party to the other under any provision of
     this Agreement shall constitute the dedication of that Party's system or
     any portion thereof to the other Party or to the public or affect the
     status of PGandE as an independent public utility corporation or Seller as
     an independent individual or entity and not a public utility.

                                      A-18
<PAGE>

     A-11 SEVERAL OBLIGATIONS

          Except where specifically stated in this Agreement to be otherwise,
     the duties, obligations, and liabilities of the Parties are intended to be
     several and not joint or collective. Nothing contained in this Agreement
     shall ever be construed to create an association, trust, partnership, or
     joint venture or impose a trust or partnership duty, obligation, or
     liability on or with regard to either Party. Each Party shall be liable
     individually and severally for its own obligations under this Agreement.

     A-12 NON-WAIVER

          Failure to enforce any right or obligation by either Party with
     respect to any matter arising in connection with this Agreement shall not
     constitute a waiver as to that matter or any other matter.

     A-13 ASSIGNMENT

          Neither Party shall voluntarily assign its rights nor delegate its
     duties under this Agreement, or any part of such rights or duties, without
     the written consent of the other Party, except in connection with the sale
     or merger of a substantial portion of its properties. Any such assignment

                                      A-19
<PAGE>

     or delegation made without such written consent shall be null and
     void. Consent for assignment shall not be withheld unreasonably. Such
     assignment shall include, unless otherwise specified therein, all of
     Seller's rights to any refunds which might become due under this Agreement.

     A-14 CAPTIONS

          All indexes, titles, subject headings, section titles, and similar
     items are provided for the purpose of reference and convenience and are not
     intended to affect the meaning of the contents or scope of this Agreement.

     A-15 CHOICE OF LAWS

          This Agreement shall be interpreted in accordance with the laws of the
     State of California, excluding any choice of law rules which may direct the
     application of the laws of another jurisdiction.

     A-16 GOVERNMENTAL JURISDICTION AND AUTHORIZATION

          Seller shall obtain any governmental authorizations and permits
     required for the construction and operation of the Facility. Seller shall
     reimburse PGandE for any and all losses, damages, claims, penalties, or
     liability it incurs as a result of Seller's failure to obtain or maintain
     such authorizations and permits.

                                      A-20
<PAGE>

     A-17 NOTICES

          Any notice, demand, or request required or permitted, to be given by
     either Party to the other, and any instrument required or permitted to be
     tendered or delivered by either Party to the other, shall be in writing
     (except as provided in Section E-3) and so given, tendered, or delivered,
     as the case may be, by depositing the same in any United States Post Office
     with postage prepaid for transmission by certified mail, return receipt
     requested, addressed to the Party, or personally delivered to the Party, at
     the address in Article 9 of this Agreement. Changes in such designation may
     be made by notice similarly given.

     A-18 INSURANCE

     A-18.1 General Liability Coverage

          (a) Seller shall maintain during the performance hereof, General
     Liability Insurance' of not less than $1,000,000 if the Facility is over
     100 kW, $500,000 if the Facility is over 20 kW to 100 kW, and $100,000 if
     the Facility is 20 kW or below of combined single limit or equivalent for
     bodily injury, personal injury, and property damage as the result of any
     one occurrence.

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

     1.   Governmental agencies which have an established record of
          self-insurance may provide the required coverage through
          self-insurance.

                                      A-21
<PAGE>

          (b) General Liability Insurance shall include coverage for
     Premises-operations, Owners and Contractors Protective, Products/Completed
     Operations Hazard, Explosion, Collapse, Underground, Contractual Liability,
     and Broad Form Property Damage including Completed Operations.

          (c) such insurance, by endorsement to the policy(ies), shall include
     PGandE as an additional insured if the Facility is over 100 kW insofar as
     work performed by Seller for PGandE is concerned, shall contain a
     severability of interest clause, shall provide that PGandE shall not by
     reason of its inclusion as an additional insured incur liability to the
     insurance carrier for payment of premium for such insurance, and shall
     provide for 30-days' written notice to PGandE prior to cancellation,
     termination, alteration, or material change of such insurance.

     A-18.2 Additional Insurance Provisions

          (a) Evidence of coverage described above in Section A-18.1 1 shall
     state that coverage provided is primary and is not excess to or
     contributing with any insurance or self-insurance maintained by PGandE.

          (b) PGandE shall have the right to inspect or obtain a copy of the
     original policy(ies) of insurance.

                                      A-22
<PAGE>

          (c) Seller shall furnish the required certificates' and endorsements
     to PGandE prior to commencing operation.

          (d) All insurance certificates', endorsements, cancellations,
     terminations, alterations, and material changes of such insurance shall be
     issued and submitted to the following:

                     PACIFIC GAS AND ELECTRIC COMPANY
                     Attention: Manager - Insurance Department
                     77   Beale Street, Room E280
                     San Francisco, CA 94106

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

     1    A governmental agency qualifying to maintain self-insurance should
          provide a statement of self-insurance.

                                      A-23
<PAGE>

                                   APPENDIX B

                             ENERGY PAYMENT OPTIONS

          Energy Payment Option 1 - Forecasted Energy Prices

          Pursuant to Article 4, the energy payment calculation for Seller's
     energy deliveries during each year of the fixed price period shall include
     the appropriate prices for such year in Table B-l, multiplied by the
     percentage Seller has specified in Article 4. If Seller has selected
     Curtailment Option B in Article 7, the forecasted off-peak hours' energy
     prices listed in Table B-1 shall be adjusted upward by 7.7% for Period A
     and 9.6% for Period B.

                                      B-1
<PAGE>

                                    TABLE B-I

                        Forecasted Energy Price Schedule

<TABLE>
<CAPTION>
                            Forecasted Energy Prices*, (cent)/kWh
     Year of                -------------------------------------
     Energy                  Period A                        Period B             Weighted
     Deliv-     ------------------------------  -------------------------------  Annual
     eries      On-Peak  Partial-Peak Off-Peak  On-Peak  Partial-Peak  Off-Peak  Average
     -----      -------  ------------ --------  -------  ------------  --------  -------

       <S>        <C>       <C>         <C>       <C>        <C>         <C>       <C>
       1983       5.36      5.12        4.94      5.44       5.31        5.19      5.18
       1984       5.66      5.40        5.22      5.74       5.61        5.48      5.47
       1985       5.75      5.48        5.30      5.83       5.69        5.56      5.55

       1986       5.99      5.72        5.52      6.08       5.94        5.80      5.79
       1987       6.38      6.08        5.88      6.47       6.32        6.17      6.16
       1988       6.94      6.62        6.39      7.03       6.87        6.71      6.70

       1989       7.60      7.25        7.00      7.70       7.53        7.35      7.34
       1990       8.12      7.74        7.48      8.23       8.04        7.85      7.84
       1991       8.64      8.24        7.96      8.75       8.56        8.35      8.34

       1992       9.33      8.90        8.60      9.46       9.24        9.02      9.01
       1993      10.10      9.63        9.30     10.23      10.00        9.76      9.75
       1994      10.91     10.41       10.06     11.06      10.81       10.55     10.54

       1995      11.79     11.25       10.87     11.96      11.68       11.40     11.39
       1996      12.67     12.09       11.68     12.85      12.56       12.25     12.24
       1997      13.61     12.98       12.54     13.79      13.48       13.15     13.14
</TABLE>

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

     *    These prices are differentiated by the time periods as defined in
          Table B-4.

                                      B-2
<PAGE>

     Energy Payment option 2 - Levelized Energy Prices

          Pursuant to Article 4, the energy payment calculation. for Seller's
     energy deliveries during the fixed price period shall include the
     appropriate prices set forth in Table B-2 for the year in which energy
     deliveries begin and term of agreement, multiplied by the percentage Seller
     has specified in Article 4. If Seller has selected Curtailment Option B in
     Article 7, the levelized off-peak hours' energy prices listed in Table B-2
     shall be adjusted upward by 7.7% for Period A and 9.6% for Period B. The
     discount specified in (c)(vi) below, if applicable; will be applied to the
     energy payments during the fixed price period.

          During the fixed price period, Seller shall be subject to the
     following conditions and terms:

     (a)  Minimum Damages

          The Parties agree that the levelized energy prices which PGandE pays
          Seller for the energy which Seller delivers to PGandE is based on the
          agreed value to PGandE of Seller's energy deliveries during the entire
          fixed price period. In the event PGandE does not receive such full
          performance by reason of a termination, Seller shall pay PGandE an
          amount based on the difference between the net present values, at the

                                      B-3
<PAGE>

          time of termination, of the payments Seller would receive at the
          forecasted energy prices in Table B-1 and the payments Seller would
          receive at the levelized energy prices, for the remaining years of the
          fixed price period. This amount shall be calculated by assuming that
          Seller continued to generate for the remaining years of the fixed
          price period at a level equal to the average annual energy generation
          during the period of performance, and by applying the weighted annual
          average levelized price applicable to Seller's Facility and the
          weighted annual average forecasted energy prices in Table B-i for the
          remaining years of the fixed E rice period. The following formula
          shall be used to make this calculation:

                                 Y     (Fn)(A)(W)        Y    (L)(A)(W)
                           P =         ----------   -          ---------
                               (Sigma)  (1.15)n       (Sigma)  (1.15)n
                                 n=1                    n=1

          where:

                P    =   amount due PGandE.

                Y    =   number of years remaining in the fixed price period.

                Fn   =   weighted annual average forecasted energy price in the
                         ninth year after the breach, failure to perform, or
                         expiration of security, as shown in Table B-1 for the
                         corresponding calendar year.

                                      B-4
<PAGE>

                L    =   weighted annual average levelized energy price
                         applicable to Seller's Facility.

                A    =   average annual energy generation by Seller during the
                         period of performance.

                n    =   summation index; refers to the nth year following
                         termination.

                W    =   percent of Seller's energy payments based on the
                         levelized energy prices, as specified in Article 4.

     (b)  Performance Requirements

          Seller shall operate and maintain the Facility in accordance with
          prudent electrical practices in order to maximize the likelihood that
          the Facility's output as delivered to PGandE during the part of the
          fixed price period when the levelized price is below the forecasted
          price ("last part") shall equal or exceed 70% of the Facility's output
          during the part of the fixed price period when the levelized price is
          above the forecasted price ("first part"). In the event that the
          Facility's output during any year or series of years in the last part
          of the fixed price period is less than 70% of the average annual
          production during the first part of the fixed price period, PGandE
          may, at its discretion (taking into consideration events occurring
          during such year or series of years such as curtailment by PGandE,
          Seller's choice not to operate during adjusted price periods, or

                                      B-5
<PAGE>

          scheduled maintenance including major overhauls, and the probability
          that Seller's future performance will be adequate), either' request
          payment from Seller or immediately draw on the security posted, up to
          the amount equal to

          P x A-B,
              ---- , where:
               A

               P and A are as defined in Section (a) above.
               B  = Seller's average annual energy generation during the year or
               series of years in which the 70% performance requirement was not
               met.

          PGandE shall not request payment from Seller or draw on the security
          posted if the Facility's output during the last part of the fixed
          price period falls below 70% of the average annual energy generation
          during the first part of the fixed Brice period solely because of
          force majeure as defined in Section A-8, Appendix A or a lack of or
          limited availability of the primary energy resource of the Facility,
          if such energy resource is wind, water, or sunlight.

     (c)  Security

          (1)  As security for amounts which Seller may be obligated to pay
               PGandE pursuant- to Sections (a) and (b) above, Seller shall
               provide and maintain one or more of the following in an amount as
               described in Section (c)(2) below.

                                      B-6
<PAGE>

          (i)  An irrevocable bank letter of credit, delivered to and in favor
               of PGandE with terms acceptable to PGandE.

          (ii) A payment bond providing for payment to PGandE in the event of
               any failure to meet the performance requirements set forth in
               Section (b) above or breach of this Agreement by Seller. Such
               bond shall be issued by a surety company acceptable to PGandE and
               shall have terms acceptable to PGandE.

          (iii) Fully paid up, noncancellable Project Failure Insurance made
               payable to PGandE with terms of such policy(ies) acceptable to
               PGandE.

          (iv) A performance bond providing for payment to PGandE in the event
               of any failure to meet the performance requirements set forth in
               Section (b) above or breach of this Agreement by Seller. Such
               bond shall be issued by a surety company acceptable to PGandE and
               shall have terms acceptable to PGandE.

          (v)  A corporate guarantee of payment to PGandE which PGandE deems, in
               its sole discretion, to provide at least the same quality of

                                      B-7
<PAGE>

               security as subsections (i) through (iv) above.

          (vi) Other forms of security which PGandE does not deem to be
               equivalent security to those listed in subsections (i) through
               (v) above, and which PGandE, in its sole discretion, deems
               adequate. Such other forms of security may include, for example,
               a corporate guarantee or a lien, mortgage or deed of trust on the
               Facility or land upon which it is located. A 1.5% discount will
               be applied against the levelized energy price portion of PGandE's
               payments to Seller during the fixed price period if this type of
               security is provided.

     (2)  (i)  Commencing 90 days prior to the scheduled operation date and
               continuing until December 1 of the following calendar year,
               security as described in Section (c)(1) above shall be in place
               in an amount calculated in accordance with the formula set forth
               in Section (a) above, assuming Seller delivered energy through
               the and of the following calendar year and then terminated this
               Agreement. For purposes of determining the required amount of

                                      B-8
<PAGE>

               security, it shall be assumed that Seller's deliveries through
               the end of the following calendar year would. equal R x C x H,
               where:

                    R  =   nameplate rating, in kW, of the Facility.

                    C  =   estimated capacity factor of the Facility, which
                           shall be established by mutual agreement of the
                           Parties at the time of execution of this Agreement.

                    H  =   number of hours from the scheduled operation date
                           through the end of the following calendar year.

          (ii) In the second calendar year of operation and each year thereafter
               until the end of the fixed price period, from December 1 through
               December 1 of the following year, security I shall be in place in
               an amount calculated by the formula set forth in Section (a)
               above assuming Seller continued to deliver energy in each month
               through the and of the following calendar year, at a level equal
               to the average monthly energy deliveries to date, and then
               terminated this Agreement.

                                      B-9
<PAGE>

          (3)  Security must be maintained throughout the fixed price period as
               specified above. Any security with a fixed expiration date must
               be renewed by, Seller prior to that date. If such security is not
               renewed at least 30 days prior to its expiration, PGandE may, at
               its discretion, either request payment from Seller or immediately
               draw on the security posted, up to the amount calculated in
               accordance with the formula set forth in Section (a) above.

          (4)  If, at any time during the fixed price period, PGandE believes
               Seller is in material breach of this Agreement, PGandE shall so
               notify Seller in writing and Seller must remedy such breach
               within a reasonable period of time. If Seller does not so remedy,
               PGandE may, at its discretion, either request payment from Seller
               or immediately draw upon the security posted, up to the amount
               calculated in accordance with the formula set forth in Section
               (a) above, provided that if during Seller's period to remedy,
               Seller disputes PGandE's conclusion that Seller is in material
               breach, and PGandE elects to draw upon the security, the amount
               drawn upon by PGandE shall be deposited in an interest earning
               escrow account and held in such account until the dispute is
               resolved in accordance with Section (c)(5) below.

                                      B-10
<PAGE>

          (5)  Upon the written request of either Party, any controversy or
               dispute between the Parties concerning Section (c)(4) above shall
               be subject to arbitration in accordance with the provisions of
               the California Arbitration Act, Sections 1280-1294.2 of the
               California Code of Civil Procedure except as provided otherwise
               in this section. Either Party may demand arbitration by first
               giving written notice of the existence of a dispute and then
               within 30 days of such notice giving a second written notice of
               the demand for arbitration.

               Within ten days after receipt of the demand for arbitration, each
               Party shall appoint one person, who shall not be an employee of
               either Party, to hear and determine the dispute. After both
               arbitrators have been appointed, they shall within five (5) days
               select a third arbitrator.

               The arbitration hearing shall take place in San Francisco,
               California, within 30 days of the appointment of the arbitrators,
               at such time and place as they select. The arbitrators shall give
               written notice of the time of the bearing to both Parties at
               least ten days prior to the hearing. The arbitrators shall not be
               authorized to alter, extend, or modify the terms of this
               Agreement. At the hearing, each Party shall submit a proposed

                                      B-11
<PAGE>

               written decision, and any relevant evidence may be presented. The
               decision of the arbitrators must' consist of selection of one of
               the two proposed decisions, in its entirety.

               The decision of any two arbitrators shall be binding and
               conclusive as to disputes relating to Section (c)(4) only. Upon
               determining the matter, the arbitrators shall promptly execute
               and acknowledge their decision and deliver a copy to each Party.
               A judgment confirming the award may be rendered by any superior
               court having jurisdiction. Each Party shall bear its own
               arbitration costs and expenses, including the cost of the
               arbitrator it selected, and the costs and expenses of the third
               arbitrator shall be divided equally between both Parties, except
               as provided otherwise elsewhere in this Agreement.

               Pending resolution of any controversy or dispute hereunder,
               performance by each Party shall continue so as to maintain the
               status quo prior to notice of such controversy or dispute.
               Resolution of the controversy or dispute shall include payment of
               any interest accrued in the escrow account.

                                      B-12
<PAGE>

                                    TABLE B-2
                         Levelized Energy Price Schedule
<TABLE>
<CAPTION>
          For a term of agreement of 15-16 years:

          Year in
          Which                    Levelized Energy Prices*, (cent)/kWh
          Energy                   ------------------------------------
          Deliv-               Period A                         Period B              Weighted
          eries     -------------------------------  -------------------------------  Annual
          Begin     On-Peak  Partial-Peak  Off-Peak  on-Peak  Partial-Peak  Off-Peak  Average
          -----     -------  ------------  --------  -------  ------------  --------  -------
          <S>        <C>         <C>         <C>       <C>        <C>         <C>      <C>
          1983       5.76        5.50        5.31      5.85       5.71        5.58     5.57
          1984       6.06        5.78        5.58      6.14       6.00        5.86     5.85
          1985       6.41        6.11        5.91      6.50       6.35        6.20     6.19

          1986       6.85        6.54        6.32      6.95       6.79        6.63     6.62
          1987       7.37        7.03        6.79      7.47       7.30        7.13     7.12
          1988       7.96        7.60        7.34      8.07       7.89        7.70     7.69

          For a term of agreement of 17-19 years:

          Year in
          Which                    Levelized Energy Prices*, (cent)/kWh
          Energy                   ------------------------------------
          Deliv-               Period A                         Period B              Weighted
          eries     -------------------------------  -------------------------------  Annual
          Begin     On-Peak  Partial-Peak  Off-Peak  on-Peak  Partial-Peak  Off-Peak  Average
          -----     -------  ------------  --------  -------  ------------  --------  -------
          1983       5.90        5.63        5.44      5.98       5.84        5.71     5.70
          1984       6.23        5.95        5.74      6.32       6.18        6.03     6.02
          1985       6.60        6.30        6.08      6.69       6.53        6.38     6.37

          1986       7.06        6.73        6.51      7.16       7.00        6.83     6.82
          1987       7.60        7.25        7.00      7.70       7.53        7.35     7.34
          1988       8.21        7.83        7.57      8.32       8.13        7.94     7.93

          For a term of agreement of 20-30 years:

          Year in
          Which                    Levelized Energy Prices*, (cent)/kWh
          Energy                   ------------------------------------
          Deliv-               Period A                         Period B              Weighted
          eries     -------------------------------  -------------------------------  Annual
          Begin     On-Peak  Partial-Peak  Off-Peak  on-Peak  Partial-Peak  Off-Peak  Average
          -----     -------  ------------  --------  -------  ------------  --------  -------
          1983       6.49        6.20        5.98      6.58       6.43        6.28     6.27
          1984       6.90        6.58        6.35      6.99       6.83        6.67     6.66
          1985       7.34        7.00        6.76      7.44       7.27        7.10     7.09

          1986       7.88        7.51        7.26      7.99       7.81        7.62     7.61
          1987       8.49        8.10        7.82      8.61       8.41        8.21     8.20
          1988       9.16        8.74        8.44      9.29       9.08        8.86     8.85
</TABLE>

          -----------------
          * These prices are differentiated by the time periods as defined in
            Table B-4.

                                      B-13
<PAGE>

          Energy Payment Option 3    - Incremental Energy Rate

          During the period specified in Article 4, annual adjustments to
     Seller's energy payments shall be made as described below.

          At the end of each calendar year, the Derived Incremental Energy Rate
     (with units expressed in Btu/kWh) will be calculated as follows:

          Derived Incremental Energy Rate (DIER)= B
                                                -----
                                                A x C

          where:

               A    = the total kWh delivered by Seller during the calendar
                    year, excluding any kWh delivered when Seller was asked to
                    curtail deliveries under Curtailment Option A or when Seller
                    was asked to take adjusted prices under Curtailment Option
                    B.

               B    = the total dollars paid for the energy described for A
                    above.

               C    = the weighted average price paid during the calendar year
                    by PGandE's Electric Department for oil and natural gas for
                    PGandE's fossil steam plants, expressed in $/Btu on a gas
                    Btu basis.

                                      B-14
<PAGE>

          If the DIER is between the upper and lower Incremental Energy Rate
     Bounds specified for that year in Table B-3 for the curtailment option
     selected by Seller, no additional payment is due either Party.

          If the DIER is below the lower Incremental Energy Rate Bound, PGandE
     shall pay Seller an amount calculated as follows:

                     (Lower Incremental
          PS  =       Energy Rate Bound   - DIER)(A)(C)

          where:

          PS   =      additional payment due Seller.
          DIER =      Derived Incremental Energy Rate.

          PGandE shall add this payment to the first payment made to Seller
     following the calculation.

          If the DIER is above the upper Incremental Energy Rate Bound, Seller
     shall pay PGandE an amount calculated as follows:

          PB   =     (DIER - Upper Incremental) (A)(C)
                      Energy Rate Bound

          where:

          PS   =      amount due PGandE.
          DIER =      Derived Incremental Energy Rate.

                                      B-15
<PAGE>

          This amount shall be deducted from the first payment made to Seller
          following the calculation. If there is any remaining amount due
          PGandE, PCandE may, at its option, invoice Seller' with such payment
          due within 30 days or deduct this amount from future payments due
          Seller.

                                      B-16
<PAGE>

                                    TABLE B-3

                     Forecasted Incremental Energy Rates and
                         Incremental Energy Rate Bounds

          Curtailment Option A:

<TABLE>
<CAPTION>
                                          Incremental
                     Forecasted              Energy        Upper Incremental        Lower Incremental
                     Incremental           Rate Band             Energy                   Energy
                        Energy            Width from          Rate Bound,              Rate Bound,
                        Rates              Article 4            Btu/kWh                  Btu/kWh
                       Btu/kWh              Btu/kWh           (column (a)             [column (a)]
          Year           (a)                  (b)           plus column (b)]        minus column (b)]
          ----           ---                  ---           ----------------        -----------------
          <S>           <C>
          1984          9,000             -----------         -----------              -----------
          1985          9,050             -----------         -----------              -----------

          1986          8,840             -----------         -----------              -----------
          1987          8,850             -----------         -----------              -----------
          1988          8,960             -----------         -----------              -----------

          1989          8,820             -----------         -----------              -----------
          1990          8,540             -----------         -----------              -----------
          1991          8,540             -----------         -----------              -----------

          1992          8,540             -----------         -----------              -----------
          1993          8,540             -----------         -----------              -----------
          1994          8,540             -----------         -----------              -----------

          1995          8,540             -----------         -----------              -----------
          1996          8,540             -----------         -----------              -----------
          1997          8,540             -----------         -----------              -----------

          1998          8,540             -----------         ------------             -----------
</TABLE>

                                      B-17
<PAGE>

                              TABLE B-3 (continued)

<TABLE>
<CAPTION>
          Curtailment Option B:

                                           Incremental
                     Forecasted              Energy        Upper Incremental        Lower Incremental
                     Incremental           Rate Band             Energy                   Energy
                        Energy            Width from          Rate Bound,              Rate Bound,
                        Rates              Article 4            Btu/kWh                  Btu/kWh
                       Btu/kWh              Btu/kWh           (column (a)             [column (a)]
          Year           (a)                  (b)           plus column (b)]        minus column (b)]
          ----           ---                  ---           ----------------        -----------------
          <S>           <C>
          1984          9,440             -----------         -----------              -----------
          1985          9,500             -----------         -----------              -----------

          1986          9,280             -----------         -----------              -----------
          1987          9,290             -----------         -----------              -----------
          1988          9,400             -----------         -----------              -----------

          1989          9,270             -----------         -----------              -----------
          1990          8,970             -----------         -----------              -----------
          1991          8,970             -----------         -----------              -----------

          1992          8,970             -----------         -----------              -----------
          1993          8,970             -----------         -----------              -----------
          1994          8,970             -----------         -----------              -----------

          1995          8,970             -----------         -----------              -----------
          1996          8,970             -----------         -----------              -----------
          1997          8,970             -----------         -----------              -----------

          1998          8,970             -----------         ------------             -----------
</TABLE>

                                      B-18
<PAGE>

                                    TABLE B-4
                                  Time Periods

<TABLE>
<CAPTION>
                                              Monday                       Sundays
                                              through                        and
                                              Friday2      Saturdays2     Holidays
                                              -------      ----------     --------

Seasonal Period A
May 1 through September 30)

          <S>                                <C>           <C>             <C>
          On-Peak                            12:30 p.m.
                                                 to
                                              6:30 p.m.

          Partial-Peak                        8:30 a.m      8:30 a.m.
                                                 to            to
                                             12:30 p.m     10:30 p.m.

                                              6:30 p.m
                                                 to
                                             10:30 p.m

          Off-Peak                           10:30 p.m.    10:30 p.m.      All Day
                                                 to            to
                                              8:30 a.m.     8:30 a.m.

          Seasonal Period B
           (October 1 through April 30)

          On-Peak                             4:30 p.m
                                                 to
                                              8:30 p.m

          Partial -Peak                       8:30 p.m.     8:30 a.m.
                                                 to            to
                                             10:30 p.m.    10:30 p.m.
                                              8:30 a.m.
                                                 to
                                              4:30 p.m.

          Off-Peak                           10:30 p.m.    10:30 p.m.      All Day
                                                 to            to
                                              4:30 p.m.     8:30 a.m.
</TABLE>

          -----------------
          1    This table is subject to change to accord with the on-peak,
               partial peak, and off-peak periods as defined in PGandE's own
               rate schedules for the sale of electricity to its large
               industrial customers.

          2    Except the following holidays: New Year's Day, Washington's
               birthday, Memorial Day, Independence Day, Labor Day, Veteran's
               Day. Thanksgiving Day, and Christmas Day, as specified in Public
               Law 90-363 (5 U.S.C.A. Section 6103(a)).

                                      B-19
<PAGE>

                                   TABLE B-5

                                  ENERGY PRICES

                   Energy Prices Effective February1I - April 30, 1905

          The energy purchase price calculations which will apply to energy
     deliveries determined from.. meter readings taken during February. March.
     and April 1986, are as follows:

<TABLE>
<CAPTION>
                                         (a)                    (b)                   (c)                         (d)
                                                                               Revenue Requirement          Energy Purchase
                                     Incremental                                    for Cash                     Price4
          Time Period                Energy Rate1        cost of Energy2       Working,Cap1tal3           (d)= [(a) x (b)] + (c)
          ----------                 ------------        ---------------           --------               ---------------------
                                       (Btu/kWh)            ($/102 Btu)             ($/kWh)                       ($/kWh)
          <S>                          <C>                  <C>                    <C>                           <C>
          February I - April 30
          (Period   B)

          Time of
          Delivery Basis:

            On-Peak                    16,320               5.2394                 0.00053                       0.08604
            Partial-Peak               15,689               5.2394                 0.0005l                       0.06271
            Off-Peak                   11.625               5.2394                 0.00038                       0.06129

          Seasonal Average             13,692               5.2394                 0.00045                       0.07219
           (Period B)
</TABLE>

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

          1    Incremental energy rates (Btu/kWh) for Seasonal Period A and
               Seasonal Period B are derived from the marginal energy costs
               (including variable operating and maintenance expense) adopted by
               the CPUC in Decision No. 83-12-068 (page 339). They are based
               upon natural gas as the incremental fuel and weighted average
               hydroelectric power conditions.

          2    Cost of natural gas under PGandE Gas Schedule No. G-5S effective
               February 1, 1985 per Advice No. 1304-G.

          3    Revenue Requirement for Cash Working Capital as prescribed by the
               CPIIC in Decision No. 83-12-066.

          3    Energy Purchase Price = (Incremental Energy Rate x Cost of
               Energy) Revenue Requirement for Cash Working Capital. The energy
               purchase price excludes the applicable energy line loss
               adjustment factors. however, as ordered by Ordering Paragraph No.
               12(j) of CPUC Decision No. 82-12-120, this figure is currently
               1.0 for transmission and primary distribution loss adjustments
               and is equal to marginal cost line loss adjustment factors for
               the secondary distribution voltage level. These factors may be
               changed by the CPUC in the future. The currently applicable
               energy loss adjustment factors are shown in Table 11-6.

                                      B-20
<PAGE>

                                    TABLE B-6

<TABLE>
<CAPTION>
                         Energy Loss Adjustment Factorsl

                                                                      Primary               Secondary
                                              Transmission          Distribution          Distribution
                                              ------------          ------------          ------------

          <S>                                    <C>                    <C>                 <C>
          Seasonal Period A
           (May 1 through September 30)

            On-Peak                               1.0                   1.0                 1.0148
            Partial-Peak                          1.0                   1.0                 1.0131
            Off-Peak                              1.0                   1.0                 1.0093

          Seasonal Period B
          (October 1 through April 30)

            On-Peak                               1.0                   1.0                 1.0128
            Partial-Peak                          1.0                   1.0                 1.0119
            Off-Peak                              1.0                   1.0                 1.0087
</TABLE>

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

          1    The applicable energy loss adjustment factors may be revised
               pursuant to orders of the CPUC.

                                      B-21
<PAGE>

                                   APPENDIX C

                               CURTAILMENT OPTIONS

          Seller has two options regarding curtailment of energy deliveries and
     Seller has made its selection in Article 7. The two options are as follows:

          CURTAILMENT OPTION A - HYDRO SPILL AND
                                 NEGATIVE AVOIDED COST

          (a) In anticipation of a period of hydro spill conditions, as defined
     by the CPUC, PGandE may notify Seller that any purchases of energy from
     Seller during such period shall be at hydro savings prices quoted by
     PGandE. if Seller delivers energy to PGandE during any such period, Seller
     shall be paid hydro savings prices for those deliveries in lieu of prices
     which would otherwise be applicable. The hydro savings prices shall be
     calculated by PGandE using the following formula:

                                     AQF - S
                                     ------- x PP             (> or equal to 0)
                                       AQF

     where:

          AQF   =   Energy, in kWh, projected to be available during hydro spill
                    conditions from all qualifying facilities under agreements
                    containing hydro savings price provisions.

                                       C-1
<PAGE>

          S     =   Potential energy, in kWh, from PGandE hydro facilities which
                    will be spilled if all AQF is delivered to PGandE.

          PP    =   Potential energy, in kWh, from PGandE hydro facilities which
                    will be spilled if all AQF is delivered to PGandE. Prices
                    published by PGandE for purchases during other than hydro
                    spill conditions.

          PGandE shall give Seller notice of general periods when hydro spill
     conditions are anticipated, and shall give Seller as much advance notice as
     practical of any specific hydro spill period and the hydro savings price
     which will be applicable during such period.

          (b) PGandE shall not be obligated to accept or pay for and may require
     Seller with a Facility with a nameplate rating of one megawatt or greater
     to interrupt or reduce deliveries of energy during periods when PGandE
     would incur negative avoided costs (as defined by the CPUC) due to
     continued acceptance of energy deliveries under this Agreement. Whenever
     possible, PGandE shall give Seller reasonable notice of the possibility
     that interruption or reduction of deliveries may be required.

          (c) Before interrupting or reducing deliveries under subsection (b),
     above, and before invoking hydro savings prices under subsection (a),
     above, PGandE shall take reasonable steps to make economy sales of the
     surplus energy giving rise to the condition. If such economy sales are
     made, while the surplus energy condition exists seller shall be paid at

                                      C-2
<PAGE>

     the economy sales price obtained by PGandE in lieu of the otherwise
     applicable prices.

          (d) If Seller is selling net energy output to PGandE and
     simultaneously purchasing its electrical needs from PGandE and Seller
     elects not to sell energy to PGandE at the hydro savings price pursuant to
     subsection (a) or when PGandE curtails deliveries of energy pursuant to
     subsection (b), Seller shall not use such energy to meet its electrical
     needs but shall continue to purchase all its electrical needs from PGandE.
     If Seller is selling surplus energy output to PGandE, subsections (a) or
     (b) shall only apply to the surplus energy output being delivered to
     PGandE, and Seller can continue to internally use that generation it has
     retained for its own use.

                  CURTAILMENT OPTION B - ADJUSTED PRICE PERIOD

          (a) In each calendar year, the price which PGandE is obligated to pay
     Seller for energy deliveries during 1,000 off-peak hours (as defined in
     Table B-4, Appendix B) may be adjusted to a price equal to, but not in
     excess of, PGandE's available alternative source. This adjusted price shall
     be effective under any of the following conditions:

          (i) when PGandE's energy source at the margin is not a PGandE oil- or
     gas-fueled plant, and PGandE can replace Seller's energy with energy from

                                      C-3
<PAGE>

     this source at a cost less than the price paid to Seller;

          (ii) when PGandE would incur negative avoided costs (as defined by the
     CPUC) due to continued acceptance of energy deliveries under this
     Agreement; or

          (iii) when PGandE is experiencing minimum system operations.

          During any of the conditions described above the adjusted price may be
     zero.

          (b) Whenever possible, PGandE shall give Seller reasonable notice of
     any price adjustment for energy deliveries and its probable duration.

          (c) If Seller is selling net energy output to PGandE and
     simultaneously purchasing its electrical needs from PGandE and Seller
     elects not to sell energy to PGandE at the adjusted price, Seller shall not
     use such energy to meet its electrical needs but shall continue to purchase
     all its electrical needs from PGandE.

          (d) After Seller receives notice of the probable duration of the
     period during which the adjusted price will be paid, Seller may elect to
     perform maintenance during such  period and so inform the PGandE employee

                                      C-4
<PAGE>

          in charge at the designated PGandE switching center prior to the time
          when the adjusted price period is expected to begin. If Seller makes
          such election, the number of off-peak hours of probable duration
          quoted in PGandE's notice to Seller shall be applied to the 1,000-hour
          calendar year limitation set forth in this section. After an election
          to do maintenance, if Seller makes any deliveries of energy during the
          quoted probable duration period, Seller shall be paid the adjusted
          price quoted in its notice from PGandE without regard to any
          subsequent changes on the PGandE system which may alter the adjusted
          price or shorten the actual duration of the condition.

                                      C-5
<PAGE>

                                   APPENDIX D

                              AS-DELIVERED CAPACITY

     D-1 AS-DELIVERED CAPACITY PAYMENT OPTIONS

          Seller has two options for as-delivered capacity payments and Seller
     has made its selection in Article 5. The two options are as follows:

                     AS-DELIVERED CAPACITY PAYMENT OPTION 1

          PGandE shall pay Seller for as-delivered capacity at prices authorized
     from time to time by the CPUC. The as-delivered capacity prices in effect
     on the date of execution are calculated as shown in Exhibit D-l.

                     AS-DELIVERED CAPACITY PAYMENT OPTION 2

          During the fixed price period, the as-delivered capacity prices will
     be calculated in accordance with Exhibit D-1 and the forecasted shortage
     costs in Table D-2.

          For the remaining years of the term of agreement, PGandE shall pay
     Seller for as-delivered capacity at the higher of:

                                      D-1
<PAGE>

          (i) prices authorized from time to time by the, CPUC;

          (ii) the as-delivered capacity prices that were paid Seller in the
               last year of the fixed price period; or

          (iii) the as-delivered capacity prices in effect in the first year
               following the end of the fixed price period, provided that the
               annualized shortage cost from which these prices are derived does
               not exceed the annualized value of a gas turbine.

              D-2 AS-DELIVERED CAPACITY IN EXCESS OF FIRM CAPACITY

          The amount of capacity delivered in excess of firm capacity will be
     considered as-delivered capacity. This as-delivered capacity is based on
     the total kilowatt-hours delivered each month during all on-peak,
     partial-peak and off-peak hours excluding any energy associated with
     generation levels equal to or less than the firm capacity.

          Seller has the two options listed in Section D-1 for payment for such
     as-delivered cam. Seller has made its selection in Article 5.

                                      D-2
<PAGE>

                                   EXHIBIT D-1

          The as-delivered capacity price (in cents per kW-hr) for power
     delivered by the Facility is the product of three factors:

               (a) The shortage cost in each year the Facility is operating.
          Currently, this shortage cost is $60 per kW-year.

               (b) A capacity loss adjustment factor which provides for the
          effect of the deliveries on PGandE's transmission and distribution
          losses based on the Seller's interconnection voltage level. The
          applicable capacity loss adjustment factors for non-remote' Facilities
          are presented in Table D-1(a). Capacity loss adjustment factors for
          remote Facilities shall be calculated individually.

               (e) An allocation factor which accounts for the different values
          of as-delivered capacity in different time periods and converts
          dollars per kW-year to cents per kWh. The current allocation factors
          are presented in Table D-1(b). The time periods to which they apply
          are shown in Table B-4, Appendix B. The allocation factors are subject
          to change from time to time.

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

     1    As defined by the CPUC.

                                      D-3
<PAGE>

                                  TABLE D-1(a)

                        Capacity Loss Adjustment Factors
                           for Non-Remotes Facilities

          Voltage Level                              Loss Adjustment Factor
          -------------                              ----------------------
          Transmission                                       .989
          Primary Distribution                               .991
          Secondary Distribution                             .991

     If the Facility is remote, the capacity loss adjustment factor is _______2.

                                  TABLE D-1(b)

                               Allocation Factors
                           for As-Delivered Capacity3

<TABLE>
<CAPTION>
                                     On-Peak           Partial-Peak           Off-Peak
                                 ((cent)-yr/$-hr)    ((cent)-yr/$-hr)     ((cent)-yr/$-hr
                                 ----------------    ----------------     ---------------
          <S>                         <C>               <C>                   <C>
          Seasonal Period A          .10835             .02055                .00002
          Seasonal Period B          .00896             .00109                .00001
</TABLE>

          -----------------
          1    As defined by the CPUC. The capacity loss adjustment factors for
               remote Facilities are determined individually.

          2    Determined individually.

          3    The units for the allocation factor, cent-yr/$-hr, are derived
               from the conversion of $/kW-yr into 9/kWh as follows:

                          (cent)/kWh     (cent)/kW-hr       (cent)-yr
                          ----------   = ------------  =  -------------
                            $/kW-yr        $/kW-yr            $-hr

          The allocation factors were prescribed by the CPUC in Decision No.
          83-12-068 and are subject to change from time to time.

                                      D-4
<PAGE>

                                    TABLE D-2

                        Forecasted Shortage Cost Schedule

                                                    Forecast Shortage
                Year                                   Cost,$/kW-Yr
                ----                                   ------------

                1983                                       70.
                1984                                       76
                1985                                       81

                1986                                       88
                1987                                       95
                1988                                      102

                1989                                      110
                1990                                      118
                1991                                      126

                1992                                      135
                1993                                      144
                1994                                      154

                1995                                      164
                1996                                      176
                1997                                      188

                                      D-5
<PAGE>

                                   APPENDIX E

                                  FIRM CAPACITY

                                    CONTENTS

          Section                                                        Page
          -------                                                        ----
            E-1        GENERAL                                           E-2

            E-2        PERFORMANCE REQUIREMENTS                          E-2

            E-3        SCHEDULED MAINTENANCEE                            E-4

            E-4        ADJUSTMENTS TO FIRM CAPACITY                      E-5

            E-5        FIRM CAPACITY PAYMENTS                            E-6

            E-6        DETERMINATION OF NATURAL FLOW DATA                E-12

            E-7        THEORETICAL OPERATION STUDY                       E-13

            E-8        DETERMINATION OF AVERAGE DRY                      E-15
                       YEAR CAPACITY RATINGS

            E-9        INFORMATION REQUIREMENTS                          E-15

            E-1O       ILLUSTRATIVE EXAMPLE                              E-16

            E-11       MINIMUM DAMAGES                                   E-19

                                      E-1
<PAGE>

                                   APPENDIX E

                                  FIRM CAPACITY

          E-l  GENERAL

               This Appendix E establishes conditions and prices under which
          PGandE shall pay for firm capacity.

               PGandE's obligation to pay for firm capacity shall begin on the
          firm capacity availability date. The firm capacity price shall be
          subject to adjustment as provided for in this Appendix E.

               The firm capacity prices in Table E-2 are applicable for
          deliveries of firm capacity beginning after December 30, 1982.

          E-2  PERFORMANCE REQUIREMENTS

               (a) To receive full capacity payments, the firm Capacity shall be
          delivered for all of the on-peak hours1 in the peak months on the
          PGandE system, which are presently the months of June, July, and
          August, subject to a 20 percent allowance for forced outages in any
          month. Compliance with this provision shall be based on the Facility's
          total on-peak deliveries for each of the peak

          --------------
          1    On-peak, partial-peak, and off-peak hours are defined in Table
               B-4, Appendix B.

                                      E-2
<PAGE>

     months and shall exclude any energy associated with generation levels
     greater than the firm capacity.

          (b) If Seller is prevented from meeting the performance requirements
     because of a forced outage on the PGandE system, a PGandE curtailment of
     Seller's deliveries, or a condition set forth in Section A-7, Appendix A,
     PGandE shall continue capacity payments. Firm capacity payments will be
     calculated in the same manner used for scheduled maintenance outages.

          (c) If Seller is prevented from meeting the performance requirements
     because of force majeure, PGandE shall continue capacity payments for
     ninety days from the occurrence of the force majeure. Thereafter, Seller
     shall be deemed to have failed to have met the performance requirements.
     Firm capacity payments will be calculated in the same manner used for
     scheduled maintenance outages.

          (d) If Seller is prevented from meeting the performance requirements
     because of exteme dry year conditions, PGandE shall continue capacity
     payments. Extreme dry year conditions are drier than those used to
     establish firm capacity pursuant to Section E-8. Seller shall warrant to
     PGandE that the Facility is a hydroelectric facility and that such
     conditions are the sole cause of Seller's inability to meet its firm
     capacity obligations.

                                      E-3
<PAGE>

          (e) If Seller is prevented from meeting the performance requirements
     for reasons other than those described above in Sections E-2(b), (c), or
     (d):

               (1) Seller shall receive the reduced firm capacity payments as
          provided in Section E-5 for a probationary period not to exceed 15
          months, or as otherwise agreed to by the Parties.

               (2) If, at the end of the probationary period Seller has not
          demonstrated that the Facility can meet the performance requirements,
          PGandE may derate the firm capacity pursuant to Section E-4(b).

     E-3 SCHEDULED MAINTENANCE

               Outage periods for scheduled maintenance shall not exceed 840
          hours (35 days) in any 12-month period. This allowance may be used in
          increments of an hour or longer on a consecutive or nonconsecutive
          basis. Seller may accumulate unused maintenance hours from one
          12-month period to another up to a maximum of 1,080 hours (45 days).
          This accrued time must be used consecutively and only for major
          overhaul's. Seller shall provide PGandE with the following advance
          notices: 24 hours for scheduled outages less than one day, one week
          for a scheduled outage of one day or more (except for major
          overhauls), and six months for a major overhaul. Seller shall not
          schedule major overhauls during the peak months (presently June, July
          and August). Seller shall make reasonable efforts to schedule or
          reschedule routine maintenance outside the peak months, and in no

                                       E-4
<PAGE>

          event shall outages for scheduled maintenance exceed 30 peak hours
          during the peak months. Seller shall confirm in writing to. PGandE
          pursuant to Article 9, within 24 hours of the original notice, all
          notices Seller gives personally or by telephone for scheduled
          maintenance.

               If Seller has selected Curtailment Option B, off-peak hours of
          maintenance performed pursuant to Section (d) of Curtailment Option B,
          Appendix C shall not be deducted from Seller's scheduled maintenance
          allowances set forth above.

          E-4     ADJUSTMENTS TO FIRM CAPACITY

               (a) Seller may increase the firm capacity with the approval of
          PGandE and receive payment for the additional capacity thereafter in
          accordance with the applicable capacity purchase price published by
          PGandE at the time the increase is first delivered to PGandE.

               (b) Seller may reduce the firm capacity at any time prior to the
          firm capacity availability date by giving written notice thereof to
          PGandE. PGandE may derate the firm capacity in accordance with Section
          E-2(e) as a result of appropriate data showing Seller has failed to
          meet the performance requirements of Section E-2.

                                      E-5
<PAGE>

          E-5  FIRM CAPACITY PAYMENTS

               The method for calculation of firm capacity payments is. shown
          below. As used below in this section, month refers to a calendar
          month.

               The monthly payment for firm capacity will be the product of the
          Period Price Factor (PPF), the Monthly Delivered Capacity (MDC), the
          appropriate capacity loss adjustment factor from Table E-1 based on
          the Facility's interconnection voltage, and the appropriate
          performance bonus factor, if any, from Table E-3, plus any allowable
          payment for outages due to scheduled maintenance. The firm capacity
          price shall be applied to meter readings taken during the separate
          times and periods as illustrated in Table B-4, Appendix B.

               The PPF is determined by multiplying the firm capacity price by
          the following Allocation Factors1:

                                                       Firm
                                                       ----             PPF
                         Allocation Factor   X   Capacity Price  = ($/kW-month)
                                                 --------------

          Seasonal           .18540             --------------     -----------
          Period A

          Seasonal           .01043             --------------     -----------
          Period B

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

          1    These allocation factors were prescribed by the CPUC in Decision
               No. 83-12-068. All allocation factors are subject to change by
               PGandE based on PGandE's marginal capacity cost allocation, as
               determined in general rate case proceedings before the CPUC.
               Seasonal Periods A end and B are defined in Table B-4, Appendix
               B.

                                      E-6
<PAGE>

          The MDC is determined in the following manner:

               (1) Determine the Performance Factor (P), which is defined as the
          lesser of 1.0 or the following quantity:

                          P  =         A
                               -----------------        (< or = 1.0)
                               C x (B-S) x (0.8*)

          Where:

               A =  Total kilowatt-hours delivered during all on-peak and
                    partial-peak hours excluding any energy associated with
                    generation levels greater than the firm capacity.

               C =  Firm capacity in kilowatts.

               B =  Total on-peak and partial-peak hours during the month.

               S =  Total on-peak and partial-peak hours during the month
                    Facility is out of service on scheduled maintenance.

               (2) Determine the Monthly Capacity Factor (MCF), which is
          computed using the following expression:

                          MCF = P x (1.0 - M)
                                          ---
                                           D

          Where:

               M =  The number of hours during the month Facility is out of
                    service on scheduled maintenance.

               D =  The number of hours in the month.

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

          * 0.8 reflects a 20% allowance for forced outage.

                                      E-7
<PAGE>

          (3) Determine the MDC by multiplying the MCF by C;

                          MDC  (kilowatts) = MCF x C

               The monthly payment for firm capacity is then determined by
          multiplying the PPF by the MDC, by the appropriate capacity loss
          adjustment factor presented from Table E-l, and by the appropriate
          performance bonus factor, if any, from Table E-3.

          monthly payment
          for firm capacity = PPF x MDC x   capacity loss   x performance
                                          adjustment factor   bonus factor

               Furthermore, the payment for a month in which there is an outage
          for scheduled maintenance shall also include an amount equal to the
          product of the average hourly firm capacity payment' for the most
          recent month in the same type of Seasonal Period (i.e., Seasonal
          Period A or Seasonal Period B) during which deliveries were made times
          the number of hours of outage for scheduled maintenance in the current
          month. Firm capacity payments will continue during the outage periods
          for scheduled maintenance provided that the provisions of Section E-3
          are met.

               During a probationary period Seller's monthly payment for firm
          capacity shall be determined by substituting for the firm capacity,

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

          1    Total monthly payment divided by the total number of hours in the
               monthly billing period.

                                      E-8
<PAGE>

          the capacity at which Seller would have met the performance
          requirements. In the event that during the probationary period Seller
          does not meet the performance requirements at whatever firm capacity
          was established for the previous month, Seller's monthly payment for
          firm capacity shall be determined by substituting the firm capacity at
          which Seller would have met the performance requirements. The
          performance bonus factor shall not be applied during probationary
          periods.

                                    TABLE E-1

          If the Facility is non-remote1 the firm capacity loss adjustment
          factors are as follows:

          Voltage Level                                Loss Adjustment Factor
          -------------                                ----------------------
          Transmission                                         .989

          Primary Distribution                                 .991

          Secondary Distribution                               .991

          If the' Facility is remote the firm capacity loss adjustment factor is
          _______________2

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

            1  Is defined by the CPUC.

            2  Determined individually.

                                      E-9
<PAGE>

                                    TABLE E-2

                          Firm Capacity Price Schedule
                          ----------------------------
                              (Levelized $/kW-year
<TABLE>
<CAPTION>
             Firm
           Capacity
            Avail-
           ability
             Date               Number of Years of Firm Capacity Delivery
             ----               -----------------------------------------
             ------- -----------------------------------------------------------------------------------------
             (Year)   1    2    3     4    5    6    7    8    9   10   11   12    13   14   15     20   25   30
             -------  -    -    -     -    -    -    -    -    -   --   --   --    --   --   --     --   --   --
            <S>      <C>  <C>  <C>   <C>  <C>  <C>  <C>  <C>  <C>  <C>  <C>  <C>  <C>  <C>  <C>   <C>  <C>   <C>
             1982    65   68    70    72   75   77   79   81   84   86   88   90   91   93    95   103  109  113

             1983    70   73    75    78   80   83   85   88   90   92   94   96   98  100   102   110  117  122

             1984    76   78    81    84   86   89   92   94   97   99  101  103  106  108   110   118  125  130

             1985    81   84    87    90   93   96   99  101  104  106  109  111  113  115   118   127  134  140

             1986    88   91    94    97  100  103  106  109  112  114  117  119  122  124   126   136  144  150

             1987    95   98   101   105  108  111  114  117  120  123  125  128  130  133   135   146  154  160
</TABLE>

                                      E-10
<PAGE>

                                    TABLE E-3

                            Performance Bonus Factor

               The following shall be the performance bonus factors applicable
          to the calculation of the monthly payments for firm capacity delivered
          by the Facility after it has demonstrated a firm capacity factor in
          excess of 85%.

                            DEMONSTRATED
                        FIRM CAPACITY FACTOR                      PERFORMANCE
                                 (%)                             BONUS FACTOR
                                 ---                             ------------

                                 85                                1.000
                                 90                                1.059
                                 95                                1.118
                                100                                1.176

               After the Facility has delivered power during the span of all of
          the peak months on the PGandE system (presently June, July, and
          August) in any year (span),

               (i) the firm capacity factor for each such month shall be
          calculated in the following manner:

                           FIRM CAPACITY FACTOR (%) =       F
                                                       ---------  x 100
                                                      (N-W) x Q

          Where:

               F  = Total kilowatt-hours delivered by Seller in any peak month
                    during all on-peak hours excluding any energy associated
                    with generation levels greater than the firm capacity.

                                      E-11
<PAGE>

               N =  Total on-peak hours during the month.

               W =  Total on-peak hours during the peak month that the Facility
                    is out of service on scheduled, maintenance.

               Q =  Firm capacity in kilowatts.

               (ii) the arithmetic average of the above firm capacity factors
          shall be determined for that span,

               (iii) the average of the above arithmetic average firm capacity
          factors for the most recent span(s), not to exceed 5, shall be
          calculated and shall become the Demonstrated Firm Capacity Factor.

               To calculate the performance bonus factor for a Demonstrated Firm
          Capacity Factor not shown in Table E-3 use the following formula:

          Performance Bonus Factor = Demonstrated Firm Capacity- Factor %
                                     -------------------------------------
                                                     85%

          SECTIONS E-6 THROUGH E-10 SHALL APPLY ONLY TO HYDROELECTRIC PROJECTS
          --------------------------------------------------------------------

          E-6  DETERMINATION OF NATURAL FLOW DATA

               Natural flow data shall be based on a period of record of at
          least 50 years and which includes historic critically dry periods.

                                      E-12
<PAGE>

          In the event Seller demonstrates that a natural flow data base of at
          least50 years would be unreasonably burdensome, PGandE shall accept a
          shorter, period of record with a corresponding reduction in the
          averaging basis set forth in section E-8. Seller shall determine the
          natural flow data by month by using one of the following methods:

                                    Method 1

               If stream flow records are available from a recognized gauging
          station on the water course being developed in the general vicinity of
          the project, Seller may use the data from them directly.

                                    Method 2

               If directly applicable flow records are not available, Seller may
          develop theoretical natural flows based on correlation with available
          flow data for the closest adjacent and similar area which has a
          recognized gauging station' using generally accepted hydrologic
          estimating methods.

          E-7  THEORETICAL OPERATION STUDY

               Based on the monthly natural flow data developed under Section
          E-6 a theoretical operation study shall be prepared by seller. Such a

                                      E-13
<PAGE>

          study shall identify the monthly capacity rating in kW and the monthly
          energy production in kWh for each month of each year. The study shall
          take into account. all relevant operating constraints, limitations,
          and requirements including but not limited to --

               (1) Release requirements for support of fish life and any other
          operating constraints imposed on the project;

               (2) Operating characteristics of the proposed equipment of the
          Facility such as efficiencies, minimum and maximum operating levels,
          project control procedures, etc.;

               (3) The design characteristics of project facilities such as head
          losses in penstocks, valves, tailwater elevation levels, etc.; and

               (4) Release requirements for purposes other than power generation
          such as irrigation, domestic water supply, etc.

               The theoretical operation study for each month shall assume an
          even distribution of generation throughout the month unless Seller can
          demonstrate that the Facility has water storage characteristics. For
          the study to show monthly capacity ratings, the Facility shall be
          capable of operating during all on-peak hours in the peak months on
          the PGandE system, which are presently the months of June, July, and
          August. If the project does not have this capability throughout each
          such month, the capacity rating in that month of that year shall be
          set at zero for purposes of this theoretical operation study.

                                      E-14
<PAGE>

          E-8  DETERMINATION OF AVERAGE DRY YEAR CAPACITY RATINGS

               Based on the results of the theoretical operation study,
          developed under Section E-7, the average dry year capacity rating
          shall be established for each month. The average dry year shall be
          based on the average of the five years of the lowest annual generation
          as shown in the theoretical operation study. once such years of lowest
          annual generation are identified, the monthly capacity rating is
          determined for each month by averaging the capacity ratings from each
          month of those years. The firm capacity shown in Article 5 shall not
          exceed the lowest average dry year monthly capacity ratings for the
          peak months on the PGandE system, which are presently the months of
          June, July, and August.

          E-9  INFORMATION REQUIREMENTS

               Seller shall provide the following information to PGandE for its
          review:

               (1) A summary of the average dry year capacity ratings based on
          the theoretical operation study as provided in Table E-4;

               (2) A topographic project map which shows the location of all
          aspects of the Facility and locations of stream gauging stations used
          to determine natural flow data;

               (3) A discussion of all major factors relevant to project
          operation;

                                      E-15
<PAGE>

               (4) A discussion of the methods and procedures used to establish
          the natural flow data. This discussion shall be in sufficient detail
          for PGandE to determine that the, methods are consistent with those
          outlined in Section E-6 and are consistent with generally accepted
          engineering practices; and

               (5) Upon specific written request by PGandE, Seller's theoretical
          operation study.

          E-10 ILLUSTRATIVE EXAMPLE

               (1) Determine natural flows - These flows are developed based on
          historic stream gauging records and are compiled by month, for a
          long-term period (normally at least 50 years or more) which covers dry
          periods which historically occurred in the 1920's and 30's and more
          recently in 1976 and 77. In all but unusual situations this will
          require application of hydrological engineering methods to records
          that are available, primarily from the USGS publication "Water
          Resources Data for California".

               (2) Perform theoretical operation study - Using the natural flow
          data compiled under (1) above a theoretical operation study is
          prepared which determines, for each month of each year, energy
          generation (kWh) and capacity rating (KW). This study is performed
          based on the Facility design, operating capabilities, constraints,
          etc., and should take into account all factors relevant to project

                                      E-16
<PAGE>

          operation. Generally such a study is done by computer which routes the
          natural flows through project features, considering additions and
          withdrawals from storage, spill, past the project, releases for
          support of fish life, etc., to determine flow available for
          generation. Then the generation and capacity amounts are computed
          based on equipment performance, efficiencies, etc.

               (3) Determine average dry year capacity ratings - After the
          theoretical project operation study is complete the five years in
          which the annual generation (kWh) would have been the lowest are
          identified. Then for each month, the capacity rating (kW) is averaged
          for the five years to arrive at a monthly average capacity rating. The
          firm capacity is then set by the Seller based on the monthly average
          dry year capacity ratings and the performance requirements of this
          appendix. An example project is shown in the attached completed Table
          E-4.

                                      E-17
<PAGE>

                                     EXAMPLE
                                    TABLE E-4

                     Summary of Theoretical Operation Study

          Project:  New Creek 1

          Water Source: West Fork New Creek

          Mode of Operation: Run of the river

          Type of Turbine: Francis Design Flow: 100 cfs Design Head: 150 feet

          Operating Characteristics1:

<TABLE>
<CAPTION>
                                  Flow        Head   (feet)    Output      Efficiency %)
                                  ----        ------------     ------     --------------
                                 (cfs)        Gross    Net      (kW)     Turbine    Generator
                                 -----        -----   ----      ----     -------    ---------

          <S>                     <C>          <C>     <C>      <C>         <C>       <C>
          Normal Operation        100          160     150      1,120       90        98
          Maximum Operation       110          160     148      1,150       85        98
          Minimum Operation        30          160     155        290       75        98
</TABLE>

          Average Dry Year Operation - Based on the average of the following
          lowest generation years: 1930, 1932, 1934, 1949, 1977.

<TABLE>
<CAPTION>
                            Energy Generation      Capacity Output         Percent of
           Month                 (kWh)                  (kW)          Total Hours Operated
           -----                 -----                  ----          --------------------
          <S>                   <C>                    <C>                     <C>
          January               855,000                1,150                   100
          February              753,000                1,120                   100
          March                 818,000                1,100                   100
          April                 727,000                1,010                   100
          May                   699,000                  940                   100
          June                  612,000                  850                   100
          July                  484,000                  650                   100
          august                305,000                  410                   100
          September             245,000                  340                   100
          October               148,800                  200                   100
          November              468,000                  650                   100
          December              595,000                  800                   100
</TABLE>

          Maximum firm capacity: 410 kW

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

          1    If Facility has a variable head, operating curves should be
               provided.

                                      E-18
<PAGE>

          E-11 MINIMUM DAMAGES

               (a) In the event the firm Capacity is derated or Seller
          terminates this Agreement, the quantity by which the firm capacity is
          derated or the firm capacity shall be used to calculate the payments
          due PGandE in accordance with Section (d).

               (b) Seller shall be invoiced by PGandE for all amounts due under
          this section. Payment shall be due within 30 days of the date of
          invoice.

               (c) If Seller does not make payments pursuant to Section (b),
          PGandE shall have the right to offset any amounts due it against any
          present or future payments due Seller.

               (d) Seller shall pay to PGandE:

                    (i) an amount equal to the difference between (a) the firm
               capacity payments already paid by PGandE, based on the original
               term of agreement and (b) the total firm capacity payments which
               PGandE would have paid based on the period of Seller's actual
               performance using the adjusted firm capacity price. Additionally,
               Seller shall pay interest, compounded monthly from the date the
               excess capacity payment was made until the date Seller repays

                                      E-19
<PAGE>

               PGandE, on all overpayments, at the published Federal Reserve
               Board three months' Prime Commercial Paper rate; plus

                    (ii) a sum equal to the amount by which the firm capacity is
               being terminated or derated times the difference between the
               current firm capacity price on the date of termination or
               deration for a term equal to the balance of the term of agreement
               and the firm capacity price, multiplied by the appropriate factor
               shown in Table E-5 below. In the event that the current firm
               capacity price is less than the firm capacity price, no payment
               under this subsection (ii) shall be due either Party.

                                    TABLE E-5

                       Amount of Firm Capacity
                        Terminated or Derated           Factor
                        ----------------------           ------

               1,000       kW or under                    0.25
                over       1,000 kW through  10,000 kW    0.75
                over      10,000 kW through  25,000 kW    1.00
                over      25,000 kW through  50,000 kW    3.00
                over      50,000 kW through 100,000 kW    4.00
                over     100,000 kW                       5.00

                                      E-20
<PAGE>

                                   APPENDIX F

                                 INTERCONNECTION

                                    CONTENTS

          Section                                                      Page
          -------                                                      ----

            F-1        INTERCONNECTION TARIFFS                         F-2

            F-2        POINT OF DELIVERY LOCATION SKETCH               F-3

            F-3        INTERCONNECTION FACILITIES FOR WHICH            F-4
                       SELLER IS RESPONSIBLE

                                      F-1
<PAGE>

          F-1    INTERCONNECTION TARIFFS

                 (The applicable tariffs in effect at the time of, execution of
                 this Agreement shall be attached.)

                                      F-2
<PAGE>

                                   ASSIGNMENT

          FOR GOOD AND VALUABLE CONSIDERATION, as set forth in the "Development
     Option and Stock Purchase Agreement," effective June 1, 1989, the
     undersigned FAYETTE ENERGY CORPORATION, a Delaware corporation ("FEC"),
     hereby assigns, transfers and conveys to ALTAMONT COGENERATION CORPORATION,
     a California corporation ("ACC"), all of FEC's right, title and interest in
     and to that certain Standard Offer #4, option #1, Power Purchase Agreement
     by and between Fayette Manufacturing Corporation and Pacific Gas and
     Electric Company, date April 15, 1985, for the delivery of 6500 kilowatts
     nameplate rating at 100% avoided costs for a cogeneration plant sited in
     the Altamont Pass in California.

     Fayette Energy Corporation

     By /s/ Jerry Fuchs
        ---------------
        Jerry Fuchs. Vice President        April 10, 1990

                                   ASSUMPTION

          IN CONSIDERATION OF THE FOREGOING ASSIGNMENT, the undersigned ALTAMONT
     COGENERATION CORPORATION hereby assumes all of the rights, duties and
     obligations of the Seller under said Standard Offer 64, Option M1, Power
     Purchase Agreement. In the event that ACC's rights under the Power Purchase
     Agreement herein assigned are terminated or ACC has received notice of
     default from POSE due to any act or failure to act by ACC, FEC may (subject

<PAGE>

     to the Power Purchase Agreement) cure such default within 90 days of
     receipt by FEC of written notice from ACC that ACC's rights have been
     terminated or that ACC has received notice of default from PG&E, and FEC
     may (subject to the Power Purchase Agreement) reassume directly all rights
     and obligations of ACC to and under the Power Purchase Agreement. ACC shall
     take all reasonable action necessary to ensure that FEC is promptly
     notified of any notice of default given to Seller under the Power Purchase
     Agreement so as to maximize the time available to FEC to ensure that the
     assigned Power Purchase Agreement is not terminated by PG&E, provided,
     however, that FEC shall not be entitled to effect any cure of such default
     on behalf of ACC if ACC is diligently proceeding to cure such default
     within the time allowed for such cure under the Power Purchase Agreement.
     ACC shall indemnify, hold harmless and defend FEC for any claim made by
     PG&E of liability of FEC for the duties and obligations of the Seller under
     the assigned Power Purchase Agreement arising during such time as ACC is
     the Seller thereunder. The rights of any subsequent assignee to the
     assigned Power Purchase Agreement shall be subject to the conditions set
     forth in this paragraph.

     Altamont Cogeneration Corporation

     By /s/ Jerry Fuchs      April 10, 1990
        ---------------
        Jerry Fuchs, PresidentExhibit 10.3
                                 AMENDMENT TO THE

                            POWER PURCHASE AGREEMENT

                                     BETWEEN

                            JRW ASSOCIATES, L.P. AND

                        PACIFIC GAS AND ELECTRIC COMPANY

                              (PG&E LOG NO. 35C045)

     THIS AMENDMENT ("Amendment") is by and between PACIFIC GAS AND ELECTRIC
COMPANY ("PG&E"), a California corporation and JRW Associates, L.P., a
California limited partnership ("Seller"). PG&E and Seller are sometimes
referred to herein individually as "Party" and collectively as the "Parties"

                                    RECITALS

     A. On December 9, 1985, Seller (or Seller's predecessor, as applicable) and
entered into a Power Purchase Agreement, (as amended, "the PPA") pursuant to
which PG&E purchases electric power from Seller and Seller sells electric power
to PG&E.

     B. On April 6, 2001, PG&E filed voluntary petition under chapter 11 of the
United States Bankruptcy Code in the San Francisco Division of the United States
Bankruptcy Court for the Northern District of California (the "Bankruptcy
Court") (In re Pacific Gas and Electric Company, Banks. Case No. 01-03923).

     C. On June 14, 2001, the Commission issued D.01-06-015, which approved as
reasonable certain non-standard PPA price modifications.

     D. Seller and PG&E now desire to enter into the PPA price modification set
forth below. Seller has advised PG&E that Seller is unable to enter into the PPA
price modification unless the Bankruptcy Court has approved this Amendment and
Seller is provided a limited option to terminate this Amendment following
Bankruptcy Court approval if Seller is unable to Arrange for fuel purchases to
accommodate the price modification contemplated under this Amendment.

                                     1 of 3

<PAGE>

                                    AMENDMENT

     In consideration of the mutual promises and covenants contained herein,
PG&E and Seller agree to as follows:

     1. INTERIM ENERGY PRICE

     Unless otherwise set fourth in the PPA, for the period commencing with the
date on which this Amendment has been executed by the Parties and ending upon
the commencement of the Fixed Rate Period, as defined in Section 2 below, the
price for energy delivered, if any, to PG&E by Seller shall be determined
pursuant to the PPA, without reference to this Amendment.

     2. FIXED ENERGY PRICE

     Commencing with this date that is the earlier of, August 1, 2001, August
16, 2001 or September 1, 2001 following approval of the Bankruptcy Court as
specified in Section 4 below (hereafter, the "Bankruptcy Court Approval Date")
and ending on July 15, 2006 (this period referred to hereafter as the "Fixed
Rate Period"), Seller elects to replace the energy price term specified in the
PPA (PG&E's "full short-run avoided costs" or "full short-run avoided operating
costs" as the case may be) with the applicable energy prices as specified in
Attachment A. No provision of the PPA other than the energy price term is or
shall be deemed to be modified, amended, waived or otherwise affected by this
Amendment. The parties agree to reasonably cooperate and contest any challenge
in any Commission proceeding that seeks to alter or modify the energy pricing
terms set fourth in Attachment A, including, but not limited to any challenge to
the reasonableness of PG&E having entered into this Amendment.

                                    2 of 3
<PAGE>

     3. SELLER'S OPTION PERIOD

     For a fifteen-day period following the Bankruptcy Court Approval Date,
Seller shall have the sole right to terminate this Amendment. Upon termination
of this Amendment pursuant to this section 3, this Amendment shall be deemed a
nullity.

     4. EFFECTIVENESS

     This Amendment shall not become effective unless and until it has been
approved by the Bankruptcy Court. If the Bankruptcy Court has not approved this
Amendment by August 31, 2001, this Amendment shall be deemed a nullity.

     5. SIGNATURES

     IN WITNESS WHEREOF, Seller and PG&E have caused this Amendment to be
executed by their authorized representatives.

PACIFIC GAS AND ELECTRIC COMPANY
a California corporation

By:   /s/ illegible
      -------------------------

Title: Director
      -------------------------

Date: 7/14/01
      -------------------------

JRW ASSOCIATES, L.P.

By:   Martin V. Quinn
      -------------------------

Title: Ex VP & COO
      -------------------------

Date: 7/13/01
      -------------------------

                       3 of 3
<PAGE>

Pacific Gas and Electric Company

[LOGO OMITTED]

June 1, 1993

JRW ASSOCIATES, L.P.
ATTN. BOB POLLOCK
   CIO WAUKESHA-PEARCE INDUSTRIES
P.O. BOX 35068
HOUSTON, TX 77235-5068

Dear Sir/Madam:

This is to notify you of a change of address for Article 9, "Notices", of the
Power Purchase Agreement (PPA) between PG&E and JRW Associates. Please direct
all future written notices to:

                Mr. Richard A. Layne
                Director, Power Finance Department, B13D
                Pacific Gas and Electric Company
                77 Beale Street, Room 1311
                P.O. Box 770000
                San Francisco, CA 94177

The address in the PPA relating to insurance matters has also changed. All
insurance certificates, endorsements, cancellations, terminations, alterations,
and material changes of such insurance must be issued and submitted to the
following:

                Pacific Gas and Electric Company
                Power Contracts Department - B23C
                Attn: Insurance Coordinator
                P.O. Box 770000, Room
                2354 San Francisco, CA 94177

CPUC Decision 93-04-001 dated April 7, 1993, adopted the Division of Ratepayer
Advocate's recommendation for modifying the reporting requirements applicable to
the quarterly report of negative avoided cost or hydro spill. The above decision
ordered that: Decision (D) 82-01-103, Ordering Paragraph 17, is modified to read
in full as follows:

     "Each utility shall promptly file a report for any quarter in which a
     negative avoided cost or hydro spill condition occurs."

     Please inform all parties in your organization of the above information. If
     you have any questions please call me a (415) 973-9434.

Sincerely,

/s/ Linda Lea Weber

Linda Lea Weber
Power Systems Engineer
(415)973-9434

<PAGE>

                                 FIRST AMENDMENT
                                     TO THE
                            POWER PURCHASE AGREEMENT
                          FOR FIRM CAPACITY AND ENERGY
                              (PG&E LOG NO. 25C045)

     This First Amendment is by and between Pacific Gas and Electric Company, a
California Corporation ("PG&E"), and JRW Associates, L.P., a California Limited
Partnership ("Seller"). It amends the Standard Offer 2 Power Purchase Agreement
signed by PG&E on December 9, 1985 and by Interpro International, Inc.
("Interpro"), Seller's predecessor in interest, on September 3, 1985
("Agreement"), for a 10,750 kW cogeneration project located at J.R. Wood, Inc.,
7916 West Bellevue Road, Atwater, California 95301.

     WHEREAS, on October 9, 1989, PG&E was notified by Interpro of the
assignment of the Agreement from Interpro to National Cogeneration Corporation
("National Cogen"), in connection with the sale of substantially all of
Interpro's assets to National Cogen, which notice was acknowledged by PG&E on
October 27, 1989; and

     WHEREAS, on February 16, 1990, Seller assumed all the rights and
obligations under the agreement in connection with the sale of substantially all
of National Cogen's assets to Seller; and

     WHEREAS, on September 26, 1990, PG&E was notified by National Cogen of the
assignment of the Agreement from National Cogen to Seller; and

     WHEREAS, on December 10, 1990, National Cogen executed a formal written
assignment of the Agreement to Seller, and

     WHEREAS, on December ___, 1990. PG&E consented in writing to the assignment
of the Agreement from National Cogen to Seller, and

     WHEREAS, PG&E and Seller wish to amend the Agreement to change certain%
provisions,

     NOW, THEREFORE, in consideration of the mutual promises and covenants
contained herein, PG&E and Seller agree as follows:

     1. All underlined terms used herein shall have the meanings ascribed to
them in APPENDIX A, Section A-1 DEFINITIONS, of the Agreement.

                                       1

<PAGE>

     2. In the space indicated in Article 2, Section (a), page 4, line 5,
insert:

          "115 kV"

     3. Article 2, Section (c), page 4, lines 16-17 shall read:

          The scheduled operation date of the Facility is December 1, 1990.

     4. In the space indicated in Article 2, Section (d), page 5, line 2,
insert:

          "10,750 kW"

5. In the space indicated in Article 2, Section (f), page 5, line 8, insert:

          "December 1, 1990"

6. Article 3, Section (a), page 6, shall read:

          PG&E shall pay Seller for firm capacity at the rate of $201 per
          kW-year under Option 2 set forth in Section C-5 of Appendix C. The
          $201 per kW-year price for firm capacity was negotiated and agreed to
          by PG&E and Seller, and represents a discount from PG&E's full avoided
          costs as approved by the CPUCC. PG&E's obligation to pay for the
          contract capacity shall begin on the actual operation date. The $201
          per kW-year price for firm capacity shall be subject to adjustment as
          provided for in Appendix D.

7. Article 4, pages 6-7, shall read:

          All written notices shall be directed as follows:

          To PG&E:
          Pacific Gas and Electric Company
          Attention: Vice President-Power Generation
          245 Market Street, Room 316
          San Francisco, California 94106

          To Seller.
          7RW Associates, L.P.
          c/o Wellhead  Electric  Company,  Inc.
          1818 11th Street, Suite 4
          Sacramento, California 95814

                                       2

<PAGE>

8. Article 7, pages 7-8 shall read:

          This Agreement shall be binding upon execution and remain in effect
          thereafter for 30 years from the actual operation date provided,
          however, that it shall terminate if Seller fails to meet the deadline
          set forth in Paragraph 2 of the Agreement dated______________, or if
          the actual operation date does not occur before April 30, 1991.

9. Article 8 is added to read:

                            ARTICLE 8 - CURTAILMENT

          Each year throughout the term of this Agreement, the Facility will be
          subject to up to 3,000 hours of curtailment during off-peak and
          super-off-peak hours. Off-peak and super-off-peak hours are those time
          periods defined in Appendix B. Table B, as modified or changed from
          time to time by the CPUC. The curtailment specified by this Article
          may be either physical curtailment or economic curtailment or a
          combination of both, as determined by PG&E in the sole exercise of its
          judgement and discretion.

IN WITNESS WHEREOF, the Parties hereto have caused this First Amendment to be
executed by their duly authorized representatives, and it is effective as of the
last date set forth below.

JRW ASSOCIATES, L.P.                            PACIFIC GAS AND ELECTRIC
JRW Cogen, Inc.,                                COMPANY
      General Partner

By:/s/ Harold E. Dittmer                        By: /s/ Robert J. Haywood
   -----------------------                         -----------------------

NAME: Harold E. Dittmer                         NAME: Robert J. Haywood

TITLE: President                                TITLE: Vice President, Power
                                                        Planning & Contracts

DATE: 12-13-90                          DATE: 12-21-90
     -----------------------                  -----------------------

                                       3
<PAGE>

                                SECOND AMENDMENT
                                ----------------

THIS SECOND AMENDMENT by and between PACIFIC GAS AND ELECTRIC COMPANY, a
California Corporation ("PG&E") and JRW ASSOCIATES, L.P., a California Limited
Partnership ("TRW") (individually, "Party", and collectively, "Parties"), amends
that cetain Standard Offer 2 Power Purchase Agreement signed by PG&E on December
9, 1985 and by Interpro International, Inc. ("Interpro"). JRW's
predecessor-in-interest, on September 3, 1985 (the "PPA"), for a 10,750 kW
cogeneration project locate A- at J.R. Wood, Inc., 7916 West Bellvue Road,
Atwater, California 953101 (PG&E Log No. 25C045).

                                    RECITALS
                                    --------

A.      The Parties executed that certain Settlement Agreement dated as of
January 14. 1992 (the "Settlement Agreement").

B.      The Settlement Agreement provides, inter alia, that if the Settlement
Agreement is approved by the California Public Utilities Commission (the
"Commission") in accordance with Paragraph 4 of the Settlement Agreement, the
parties shall amend the PPA by executing this Second Amendment

C.      On,May 8.1992, the Settlement Agreement was approved by the Commission
in accordance with Paragraph 4 of the Settlement Agreement.

                                    AGREEMENT
                                    ---------

NOW THEREFORE, in consideration of the above Recitals, and for other good and
valuable consideration, the receipt and adequacy of which are hereby
acknowledged, the Parties hereby agree as follows:

<PAGE>

     1.   Defined Terms . Capitalized or underlined terms and conditions used
herein, not otherwise defined herein or in the Settlement Agreement, shall have
the meanings given them in the PPA.

     2.   Amendment of PPA. In accordance with terms and conditions of the
Settlement Agreement, the PPA is hereby amended as follows:

          (a)  Delete Article 3(b) and substitute in its place the following:
               "PG&E shall pay Seller for energy, except for energy delivered
               during periods of economic curtailment, at prices equal to 95
               percent of PG&E's full shortrun avoided operating costs as
               approved by the CPUC."

     3.  General. Except as amended herein and by the First Amendment, and
subject to the provisions of the Settlement Agreement, which remain in full
force and effect, the PPA shall continue in full force and effect.

IN WITNESS WHEREOF, the Parties hereto have caused this Second Amendment to be
executed by their duly authorized representatives, and it is effective as of the
last date set forth below.

JRW ASSOCIATES, L.P.                           PACIFIC GAS AND ELECTRIC
JRW Cogen, Inc.,                               COMPANY
     General Partner

By: /s/ Louis M. Pearce, III                   By: /s/ Robert J. Haywood
    ------------------------                       ---------------------
NAME:  Louis M. Pearce, III                    NAME:  Robert J. Haywood
TITLE: President                               TITLE: Vice President,
                                                      Power Systems

DATE: March 11, 1993                           DATE: March 12, 1993

<PAGE>

                            POWER PURCHASE AGREEMENT

                                       FOR

                            FIRM CAPACITY AND ENERGY

                                     BETWEEN

                           INTERPRO INTERNATIONAL INC.

                                       AND

                        PACIFIC GAS AND ELECTRIC COMPANY

                                       1
<PAGE>

                            FIRM CAPACITY AND ENERGY

                            POWER PURCHASE AGREEMENT

                                    CONTENTS

   Article                                                              Page
   -------                                                              ----

        1           QUALIFYING STATUS                                    3

        2           PURCHASE OF POWER                                    4

        3           PURCHASE PRICE                                       6

        4           NOTICES                                              6

        5           DESIGNATED SWITCHING CENTER                          7

        6           TERMS AND CONDITIONS                                 7

        7           TERM OF AGREEMENT                                    7

Appendix A:               GENERAL TERMS AND CONDITIONS

Appendix B:               ENERGY PRICES

Appendix C:               FIRM CAPACITY PRICE SCHEDULE

Appendix D:               ADJUSTMENT OF CAPACITY PAYMENTS IN

                          THE EVENT OF TERMINATION OR REDUCTION

Appendix E:               INTERCONNECTION

                                       2
<PAGE>

                            FIRM CAPACITY AND ENERGY

                            POWER PURCHASE AGREEMENT

                                     BETWEEN

                           INTERPRO INTERNATIONAL INC.

                                       AND

                        PACIFIC GAS AND ELECTRIC COMPANY

     INTERPRO INTERNATIONAL INC., a Utah corporation ("Seller"), and PACIFIC GAS
AND ELECTRIC COMPANY ("PGandE"), referred to collectively as "Parties" and
individually as "Party", agree as follows:

                           ARTICLE 1 QUALIFYING STATUS

     Seller warrants that, at the date of first power deliveries from Seller's
Facility(1) and during the term of agreement, its Facility shall meet the
qualifying facility requirements established as of the effective date of this
Agreement by the Federal Energy Regulatory Commission's rules (18 Code of
Federal Regulations 292) implementing the Public Utility Regulatory Policies Act
of 1978 (16 U.S.C.A. 796, et seq.).

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

1    Underlining identifies those terms which are defined in Section A-l of
     Appendix A.

                                       3
<PAGE>

                           ARTICLE 2 PURCHASE OF POWER

     (a) Seller shall sell and deliver and PGandE shall purchase and accept
delivery of firm capacity and energy at the voltage level of ________ (1)kV as
indicated below--
               1.   Contract capacity - 8,526 kW; and
               2.   Energy - net energy output (2).

         Seller may convert its energy sale option as provided in section A-3 of
Appendix A.

     (b) Seller shall provide the firm capacity and energy set forth above from
its 10,750 kW Facility located at J. R. Wood Inc., 7916 West Bellvue Road,
Atwater, California 95301.

     (c) The scheduled operation date of the Facility is September 1, 1986. At
the end of each calendar quarter Seller shall give written notice to PGandE of
any change in the scheduled operation date.

     (d) To avoid exceeding the physical limitations of the interconnection
facilities, Seller shall limit the Facility's actual rate of delivery into the
PGandE system to __________ (1)kW.

----------

1    The Seller requests, and PGandE consents, that this blank not be filled in
     at the time of executing the Agreement because the Seller, recognizing that
     the information is not yet available to make a definitive determination of
     the number to be inserted in this blank, shall request PGandE to perform an
     interconnection study to be done in its accustomed manner of making such
     studies to determine the number to be inserted.
2    Insert either "net energy oust" or "surplus energy output" to show the
     energy sale option selected by Seller.

                                       4
<PAGE>

     (e) The primary energy source for the Facility is natural gas.

     (f) If Seller does not begin construction of its Facility by __________
(2), PGandE may reallocate the [Date] existing capacity on PGandE's transmission
and/or distribution system which would have been used to accommodate Seller's
power deliveries to other uses. In the event of such reallocation, Seller shall
pay PGandE for the cost of any upgrades or additions to PGandE's system
necessary to accommodate the output from the Facility. Such additional
facilities shall be installed, owned, and maintained in accordance with the
applicable PGandE tariff.

     (g) The transformer loss adjustment factor is ________ (3)

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

1    The appropriate number will be inserted upon completion of an
     interconnection study.

2    Seller shall provide this date in the project development schedule to be
     submitted no later than 30 days after signing the Special Facilities
     Agreement for the Facility.

3    If Seller chooses to have meters placed on Seller's side of the
     transformer, an estimated transformer loss adjustment factor of 2 percent,
     unless the Parties agree otherwise, will be applied. This estimated
     transformer loss figure will be adjusted to a measurement of actual
     transformer losses performed at Seller's request and expense.

                                       5
<PAGE>

                            ARTICLE 3 PURCHASE PRICE

     (a) PGandE shall pay Seller for firm capacity at the contract capacity
price under option 2 set forth in Section C-5 of Appendix C. The contract
capacity price is derived from PGandE's full avoided costs as approved by the
CPUC. PGandE's obligation to pay for the contract capacity shall begin on the
actual operation date. Seller elects to have its contract capacity price
determined from the firm capacity price schedule in effect on the date of
execution of this Agreement'. The contract capacity price shall be subject to
adjustment as provided for in Appendix D.

     (b) PGandE shall pay Seller for energy at prices equal to PGandE's full
short run avoided operating costs as approved by the CPUC.

     (c) The contract capacity price is applicable to deliveries of capacity
beginning after December 30,1982.

                                ARTICLE 4 NOTICES

                All written notices shall be directed as follows:

       To PGandE:                Pacific Gas and Electric Company
                                 Attention: Vice President -
                                   Electric Operations
                                 77 Beale Street
                                 San Francisco, CA  94106

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

1    Insert either "the date of execution of this Agreement" or "the actual
     operation date".

                                       6
<PAGE>

       To Seller: Interpro International Inc.
                  Attention: Patrick Cassity, President
                  3120 South 1300 East
                  Salt Lake City, Utah  84106
                  (801) 486-4684

                      ARTICLE 5 DESIGNATED SWITCHING CENTER

     The designated PGandE switching center shall be unless changed by PGandE:

                                 Yosemite District Operator
                                 560 West 15th Street, Merced, CA 95341
                                 (209) 723-3841

                         ARTICLE 6 TERMS AND CONDITIONS

     This Agreement includes the following appendices which are attached and
incorporated by reference:

       Appendix A - GENERAL TERMS AND CONDITIONS

       Appendix B - ENERGY PRICES

       Appendix C - FIRM CAPACITY PRICE SCHEDULE

       Appendix D - ADJUSTMENT OF CAPACITY PAYMENTS IN THE

                    EVENT OF TERMINATION OR REDUCTION

       Appendix E - INTERCONNECTION

                           ARTICLE 7 TERM OF AGREEMENT

     This Agreement shall be binding upon execution and remain in effect
thereafter for 30 years from the actual operation date; provided, however, that
it shall terminate if the actual operation date does not occur within five years
of the execution date.

                                       7
<PAGE>

     IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to be
executed by their duly authorized representatives and effective as of the last
date set forth below.

INTERPRO INTERNATIONAL INC.                 PACIFIC GAS AND ELECTRIC COMPANY

BY: /s/ PATRICK CASSITY                     BY: /s/ HARRY M. HOWE
    -------------------                         -----------------
    PATRICK CASSITY                             HARRY M. HOWE

                                                          Chief -
TITLE: President                            TITLE:   Siting Department

DATE SIGNED: 9-3-85                         DATE SIGNED: 12/9/85

                                       8
<PAGE>

                                   APPENDIX A

                          GENERAL TERMS AND CONDITIONS

                                    CONTENTS

Section                                                                   Page
-------                                                                   ----

A-1       DEFINITIONS                                                     A-2

A-2       CONSTRUCTION                                                    A-6

A-3       ENERGY SALE OPTIONS                                             A-10

A-4       OPERATION                                                       A-12

A-5       PAYMENT                                                         A-16

A-6       ADJUSTMENTS OF PAYMENTS                                         A-17

A-7       ACCESS TO RECORDS AND PGandE DATA                               A-17

A-8       CURTAILMENT OF DELIVERIES AND HYDRO                             A-18
          SPILL CONDITIONS

A-9       FORCE MAJEURE                                                   A-20

A-10      INDEMNITY                                                       A-22

A-ll      LIABILITY; DEDICATION                                           A-23

A-12      SEVERAL OBLIGATIONS                                             A-24

A-13      NON-WAIVER                                                      A-24

A-14      ASSIGNMENT                                                      A-24

A-15      CAPTIONS                                                        A-25

A-16      CHOICE OF LAWS                                                  A-25

A-17      GOVERNMENTAL JURISDICTION AND                                   A-25
          AUTHORIZATION

A-18      NOTICES                                                         A-26

A-19      INSURANCE                                                       A-26

                                      A-1
<PAGE>

                                   APPENDIX A

                          GENERAL TERMS AND CONDITIONS

A-1  DEFINITIONS

     Whenever used in this Agreement, appendices, and attachments hereto, the
following terms shall have the following meanings:

     Actual operation date - The day following the day during which all features
and equipment of the Facility are demonstrated to PGandE's satisfaction to be
capable of operating simultaneously to deliver power continuously into PGandE's
system as provided in this Agreement.

     Adjusted capacity price - The $/kW-year purchase price from Table B,
Appendix C for the period of Seller's actual performance.

     Capacity sale reduction - A reduction in the amount of capacity provided or
to be provided under this Agreement, other than a temporary reduction during
probationary periods under Section C-5.

     Contract capacity - That capacity identified in Article 2(a) except as
otherwise changed as provided herein.

                                      A-2
<PAGE>

     Contract capacity price - The capacity price applicable for the period from
the actual operation date through the term of agreement from either the firm
capacit price schedule, Table B of Appendix C, or the successor to Table B in
effect on the actual operation date. Seller has indicated its choice of firm
capacity price schedule in Article 3(a).

     Contract termination - The early termination of this Agreement.

     CPUC - The Public Utilities Commission of the State of California.

     Current firm capacity price - The $/kW-year capacity price from the firm
capacity price schedule published by PGandE at the time notice of termination or
reduction of contract capacity is given, for a term equal to the period from the
date of termination or reduction to the end of the term of agreement.

     Designated PGandE switching center - That switching center or other PGandE
installation identified in Article 5.

     Dispatchable - The Facility is operable and can be called upon at any time
to increase its deliveries of capacity to any level up to the contract capacity.

                                      A-3
<PAGE>

     Facility - That generation apparatus described in Article 2 and all
associated equipment owned, maintained, and operated by Seller.

     Firm capacity price schedule - The periodically published schedule of the
$/kW-year prices that PGandE offers to pay for capacity. See Table B, Appendix
C.

     Forced outage - Any outage resulting from a design defect, inadequate
construction, operator error or a breakdown of the mechanical or electrical
equipment that fully or partially curtails the electrical output of the
Facility.

     Interconnection facilities - All means required and apparatus installed to
interconnect and deliver power from the Facility to the PGandE system including,
but not limited to, connection, transformation, switching, metering,
communications, and safety equipment, such as equipment required to protect (1)
the PGandE system and its customers from faults occurring at the Facility, and
(2) the Facility from faults occurring on the PGandE system or on the systems of
others to which the PGandE system is directly or indirectly connected.
Interconnection facilities also include any necessary additions and
reinforcements by PGandE to the PGandE system required as a result of the
interconnection of the Facility to the PGandE system.

                                      A-4
<PAGE>

     Net energy output - The Facility's gross output in kilowatt-hours less
station use and transformation and transmission losses to the point of delivery
into the PGandE system. Where PGandE agrees that it is impractical to connect
the station use on the generator side of the power purchase meter, PGandE may,
at its option, apply a station load adjustment.

     Prudent electrical practices - Those practices, methods, and equipment, as
changed from time to time, that are commonly used in prudent electrical
engineering and operations to design and operate electric equipment lawfully and
with safety, dependability, efficiency, and economy.

     Scheduled operation date - The day specified in Article 2 (c) when the
Facility is, by Seller's estimate, expected to produce energy and capacity that
will be available for delivery to PGandE.

     Special facilities - Those additions and reinforcements to the PGandE
system which are needed to accommodate the maximum delivery of energy and
capacity from the Facility as provided in this Agreement and those parts of the
interconnection facilities which are owned and maintained by PGandE at Seller's
request, including metering and data processing equipment. All special
facilities shall be owned, operated, and maintained pursuant to PGandE's
electric Rule No. 21, which is attached hereto.

                                      A-5
<PAGE>

     Station use - Energy used to operate the Facility's auxiliary equipment.
The auxiliary equipment includes, but is not limited to, forced and induced
draft fans, cooling towers, boiler feed pumps, lubricating oil systems, plant
lighting, fuel handling systems, control systems, and sump pumps.

     Surplus energy output - The Facility's gross output, in kilowatt-hours,
less station use, and any other use by Seller, and transformation and
transmission losses to the point of delivery into the PGandE system.

     Term of Agreement - The period of time during which this Agreement will be
in effect as provided in Article 7.

     Voltage level - The voltage at which the Facility interconnects with the
PGandE system, measured at the point of delivery.

A-2  CONSTRUCTION

A-2.1 Land Rights

     Seller hereby grants to PGandE all necessary rights of way and easements,
including adequate and continuing access rights on property of Seller, to

                                      A-6
<PAGE>

install, operate, maintain, replace, and remove the special facilities. Seller
agrees to execute such other grants, deeds, or documents as PGandE may require
to enable it to record such rights of way and easements. If any part of PGandE's
equipment is to be installed on property owned by other than Seller, Seller
shall, at its own cost and expense, obtain from the owners thereof all necessary
rights of way and easements, in a form satisfactory to PGandE, for the
construction, operation, maintenance, and replacement of PGandE's equipment upon
such property. If Seller is unable to obtain such rights of way and easements,
Seller shall reimburse PGandE for all costs incurred by PGandE in obtaining
them. PGandE shall at all times have the right of ingress to and egress from the
Facility at all reasonable hours for any purposes reasonably connected with this
Agreement or the exercise of any and all rights secured to PGandE by law or its
tariff schedules.

A-2.2 Design, Construction, ownership, and maintenance

     (a) Seller shall design, construct, install, own, operate, and maintain all
interconnection facilities, except special facilities, to the point of
interconnection with, the PGandE system as required for PGandE to receive firm
capacity and energy from the Facility. The Facility and interconnection
facilities shall meet all requirements of applicable codes and all standards of
prudent electrical  practices and shall be maintained in a safe and prudent

                                      A-7
<PAGE>

manner. A description of the interconnection facilities for which Seller is
solely responsible is set forth in Appendix E, or if the interconnection
requirements have not yet been determined at the time of the execution of this
Agreement, the description of such facilities will be appended to this Agreement
at the time such determination is made.

     (b) Seller shall submit to PGandE the design and all specifications for the
interconnection facilities (except special facilities) and, at PGandE's option,
the Facility, for review and written acceptance prior to their release for
construction purposes. PGandE shall notify Seller in writing of the outcome of
PGandE's review of the design and specifications for Seller's interconnection
facilities (and the Facility, if requested) within 30 days of the receipt of the
design and all of the specifications for the interconnection facilities (and the
Facility, if requested). Any flaws perceived by PGandE in the design and
specifications for the interconnection facilities (and the Facility, if
requested) will be described in PGandE's written notification. PGandE's review
and acceptance of the design and specifications shall not be construed as
confirming or endorsing the design and specifications or as warranting their
safety, durability, or reliability. PGandE shall not, by reason of such review
or lack of review, be responsible for strength, details of design, adequacy, or

                                      A-8
<PAGE>

capacity of equipment built pursuant to such design and specifications, nor
shall PGandE's acceptance be deemed to be an endorsement of any of such
equipment. Seller shall change the interconnection facilities as may be
reasonably required by PGandE to meet changing requirements of the PGandE
system.

     (c) In the event it is necessary for PGandE to install interconnection
facilities for the purposes of this Agreement, they shall be installed as
special facilities.

     (d) Upon the request of Seller, PGandE shall provide a binding estimate for
the installation of interconnection facilities by PGandE.

A-2.3 Meter Installation

     (a) PGandE shall specify, provide, install, own, operate, and maintain as
special facilities all metering and data processing equipment for the
registration and recording of energy and other related parameters which are
required for the reporting of data to PGandE and for computing the payment due
Seller from PGandE.

     (b) Seller shall provide, construct, install, own, and maintain at Seller's
expense all that is required to accommodate the metering and data processing
equipment, such as, but not limited to, metal-clad switchgear, switchboards,

                                      A-9
<PAGE>

cubicles, metering panels, enclosures, conduits, rack structures, and equipment
mounting pads.

     (c) PGandE shall permit meters to be fixed on PGandE's side of the
transformer. If meters are placed on PGandE's side of the transformer, service
will be provided at the available primary voltage and no transformer loss
adjustment will be made. If Seller chooses to have meters placed on Seller's
side of the transformer, an estimated transformer loss adjustment factor of 2
percent, unless the Parties agree otherwise, will be applied.

A-3  ENERGY SALE OPTIONS

A-3.1 General

     Seller has two energy sale options, net energy output or surplus energy
output. Seller has made its initial selection in Article 2(a).

A-3.2 Energy Sale Conversion

     (a) Seller is entitled to convert from one option to the other 12 months
after execution of this Agreement, and thereafter at least 12 months after the
effective date of the most recent conversion, subject to the following
conditions:

                                      A-10
<PAGE>

          (1) Seller shall provide PGandE with a written request to convert its
     energy sale option.
          (2) Seller shall comply with all applicable tariffs on file with the
     CPUC and contracts in effect between the Parties at the time of conversion
     covering the existing and proposed (i) facilities used to serve Seller's
     premises and (ii) interconnection facilities.
          (3) Seller shall install and operate equipment required by PGandE to
     prevent PGandE from serving any part of Seller's load which is served by
     the Facility and not under contract for PGandE standby service. At Seller's
     request PGandE shall provide this equipment as special facilities.
          (4) If the energy sale conversion results in a capacity sale
     reduction, the provisions in Appendix D shall apply.

     (b) If, as a result of an energy sales conversion, Seller no longer
requires the use of interconnection facilities installed and/or operated and
maintained by PGandE as special facilities under a special Facilities Agreement,
Seller may reserve these facilities, for its future use, by continuing its
performance under its Special Facilities Agreement. If Seller does not wish to
reserve such facilities, it may terminate its Special Facilities Agreement.

                                      A-11
<PAGE>

     If Seller's energy sale conversion results in its discontinuation of its
use of PGandE facilities not covered by Seller's Special Facilities Agreement,
Seller cannot reserve those facilities for future use. Seller's future use of
such facilities shall be contingent upon the availability of such facilities at
the time Seller requests such use. If such facilities are not available, Seller
shall bear the expense necessary to install, own, and maintain the needed
additional facilities in accordance with PGandE's applicable tariff.

     (c) PGandE shall process requests for conversion in the order received. The
effective date of conversion shall depend on the completion of the changes
required to accommodate Seller's energy sale conversion.

A-4  OPERATION

A-4.1 Inspection and Approval

     Seller shall not operate the Facility in parallel with PGandE's system
until an authorized PGandE representative has inspected the interconnection
facilities, and PGandE has given written approval to begin parallel operation.
Seller shall notify PGandE of the Facility's start-up date at least 45 days
prior to such date. PGandE shall inspect the interconnecting facilities within
30 days of the receipt of such notice. If parallel operation is not authorized

                                      A-12
<PAGE>

by PGandE, PGandE shall notify Seller in writing within five days after
inspection of the reason authorization for parallel operation was withheld.

A-4.2 Facility Operation and Maintenance

     Seller shall operate and maintain its Facility according to prudent
electrical practices, applicable laws, orders, rules, and tariffs and shall
provide such reactive power support as may be reasonably required by PGandE to
maintain system voltage level and power factor. Seller shall operate the
Facility at the power factors or voltage levels prescribed by PGandE's system
dispatcher or designated representative. If Seller fails to provide reactive
power support, PGandE may do so at Seller's expense.

A-4.3 Point of Delivery

     Seller shall deliver the energy at the point where Seller's electrical
conductors (or those of Seller's agent) contact PGandE's system as it shall
exist whenever the deliveries are being made or at such other point or points as
the Parties may agree in writing. The initial point of delivery of Seller's
power to the PGandE system is set forth in Appendix E.

                                      A-13
<PAGE>

A-4.4 Operating Communications

     (a) Seller shall maintain operating communications with the designated
PGandE switching center. The operating communications shall include, but not be
limited to, system paralleling or separation, scheduled and unscheduled
shutdowns, equipment clearances, levels of operating voltage or power factors
and daily capacity and generation reports.

     (b) Seller shall keep a daily operations log for each generating unit which
shall include information on unit availability, maintenance outages, circuit
breaker trip operations requiring a manual reset, and any significant events
related to the operation of the Facility.

     (c) If Seller makes deliveries greater than one megawatt, Seller shall
measure and register on a graphic recording device power in kW and voltage in kV
at a location within the Facility agreed to by both Parties.

     (d) If Seller makes deliveries greater than one and up to and including ten
megawatts, Seller shall report to the designated PGandE switching center, twice
a day at agreed upon times for the current day's operation, the hourly readings
in kW of capacity delivered and the energy in kWh delivered since the last
report.

                                      A-14
<PAGE>

     (e) If Seller makes deliveries of greater than ten megawatts, Seller shall
telemeter the delivered capacity and energy information, including real power in
kW, reactive power in kVAR, and energy in kWh to a switching center selected by
PGandE. PGandE may also require Seller to telemeter transmission kW, kVAR, and
kV data depending on the number of generators and transmission configuration.
Seller shall provide and maintain the data circuits required for telemetering.
When telemetering is inoperative, Seller shall report daily the capacity
delivered each hour and the energy delivered each day to the designated PGandE
switching center.

     (f) If Seller provides dispatchable capacity greater than ten megawatts
pursuant to Option 1 in Section C-5 of Appendix C, Seller may be required by
PGandE to provide telemetering and control equipment to allow the Facility to
respond to system load frequency requirements on digital control from PGandE.

A-4.5 Meter Testing and Inspection

     (a) All meters used to provide data for the computation of the payments due
Seller from PGandE shall be sealed, and the seals shall be broken only by PGandE
when the meters are to be inspected, tested, or adjusted.

                                      A-15
<PAGE>

     (b) PGandE shall inspect and test all meters upon their installation and
annually thereafter. At Seller's request and expense, PGandE shall inspect or
test a meter more frequently. PGandE shall give reasonable notice to Seller of
the time when any inspection or test shall take place, and Seller may have
representatives present at the test or inspection. If a meter is found to be
inaccurate or defective, PGandE shall adjust, repair, or replace it at its
expense in order to provide accurate metering.

A-4.6 Adjustments to Meter Measurements

     If a meter fails to register, or if the measurement made by a meter during
a test varies by more than two percent from the measurement made by the standard
meter used in the test, an adjustment shall be made correcting all measurements
made by the inaccurate meter for --(1) the actual period during which inaccurate
measurements were made, if the period can be determined, or if not, (2) the
period immediately preceding the test of the meter equal to one-half the time
from the date of the last previous test of the meter, provided that the period
covered by the correction shall not exceed six months.

A-5  PAYMENT

     PGandE shall mail to Seller not later than 30 days after the end of each
monthly billing period (1) a statement showing the capacity and energy delivered

                                      A-16
<PAGE>

to PGandE during on-peak, partial-peak, and off-peak periods during the monthly
billing period, (2) PGandE's computation of the amount due Seller, and (3)
PGandE's check in payment of said amount. Except as provided in Section A-6, if
within 30 days of receipt of the statement Seller does not make a report in
writing to PGandE of an error, Seller shall be deemed to have waived any error
in PGandE's statement, computation, and payment, and they shall be considered
correct and complete.

A-6  ADJUSTMENTS OF PAYMENTS

     (a) In the event adjustments to payments are required as a result of
inaccurate meters, PGandE shall use the corrected measurements described in
Section A-4.6 to recompute the amount due from PGandE to Seller for the firm
capacity and energy delivered under this Agreement during the period of
inaccuracy.

     (b) The additional payment to Seller or refund to PGandE shall be made
within 30 days of notification of the owing Party of the amount due.

A-7  ACCESS TO RECORDS AND PGandE DATA

     Each Party, after giving reasonable written notice to the other Party,
shall have the right of access to all  metering and related records including

                                      A-17
<PAGE>

operations logs of the Facility. Data filed by PGandE with the CPUC pursuant to
CPUC orders governing the purchase of power from qualifying facilities shall be
provided to Seller upon request; provided that Seller shall reimburse PGandE for
the costs it incurs to respond to such request.

A-8  CURTAILMENT OF DELIVERIES AND HYDRO SPILL CONDITIONS

     (a) PGandE shall not be obligated to accept or pay for and may require
Seller to interrupt or reduce deliveries of energy (1) when necessary in order
to construct, install, maintain, repair, replace, remove, investigate, or
inspect any of its equipment or any part of its system, or (2) if it determines
that interruption or reduction is necessary because of emergencies, forced
outages, force majeure, or compliance with prudent electrical practices.

     (b) In anticipation of a period of hydro spill conditions, as defined by
the CPUC, PGandE may notify Seller that any purchases of energy from Seller
during such period shall be at hydro savings prices quoted by PGandE. If Seller
delivers energy to PGandE during any such period, Seller shall be paid hydro
savings prices for those deliveries in lieu of prices which would otherwise be
applicable. The hydro savings prices shall be calculated by PGandE using the
following formula:

                                      A-18
<PAGE>

                                     AQF - S
                                     ------- X PP
                                       AQF

where:

AQF   =   Energy, in kWh, projected to be available during hydro spill
          conditions from all qualifying facilities under agreements containing
          hydro savings price provisions.
S     =   Potential energy, in kWh, from PGandE hydro facilities which will be
          spilled if all AQF is delivered to PGandE.
PP    =   Prices published by PGandE for purchases during other than hydro
          spill conditions.

     (c) PGandE shall not be obligated to accept or pay for and may require
Seller with a Facility with a nameplate rating of one megawatt or greater to
interrupt or reduce deliveries of energy during periods when purchases under
this Agreement would result in costs greater than those which PGandE would incur
if it did not make such purchases but instead generated an equivalent amount of
energy itself.

     (d) Whenever possible, PGandE shall give Seller reasonable notice of the
possibility that interruption or reduction of deliveries under subsections (a)
or (c), above, may be required. PGandE shall give Seller notice of general
periods when hydro spill conditions are anticipated, and shall give Seller as
much advance notice as practical of any specific hydro spill period and the

                                      A-19
<PAGE>

hydro savings price which will be applicable during such period. Before
interrupting or reducing deliveries under subsection (c)., above, and before
invoking hydro savings prices under subsection (b), above, PGandE shall take
reasonable steps to make economy sales of the surplus energy giving rise to the
condition. If such economy sales are made, while the surplus energy condition
exists Seller shall be paid at the economy sales price obtained by PGandE in
lieu of the otherwise applicable prices.

     (e) If Seller is selling net energy output to PGandE and simultaneously
purchasing its electrical needs from PGandE, energy curtailed pursuant to
subsections (b) or (c) above shall not be used by Seller to meet its electrical
needs. When Seller elects not to sell energy to PGandE at the hydro savings
price pursuant to subsection (b) or when PGandE curtails deliveries of energy
pursuant to subsection (c), Seller shall continue to purchase all its electrical
needs from PGandE. If Seller is selling surplus energy output to PGandE,
subsections (b) or (c) shall only apply to the surplus energy output being
delivered to PGandE, and Seller can continue to internally use that generation
it has retained for its own use.

A-9  FORCE MAJEURE

     (a) The term force majeure as used herein means unforeseeable causes, other
than forced outages, beyond the reasonable control of and without the fault or

                                      A-20
<PAGE>

negligence of the Party claiming force majeure including, but not limited to,
acts of God, labor disputes, sudden actions of the elements, actions by federal,
state, and municipal agencies, and actions of legislative, judicial, or
regulatory agencies which conflict with the terms of this Agreement.

     (b) If either Party because of force majeure is rendered wholly or partly
unable to perform its obligations under this Agreement, that Party shall be
excused from whatever performance is affected by the force majeure to the extent
so affected provided that:

          (1) the non-performing Party, within two weeks after the occurrence of
     the force majeure, gives the other Party written notice describing the
     particulars of the occurrence,
          (2) the suspension of performance is of no greater scope and of no
     longer duration than is required by the force majeure,
          (3) the non-performing Party uses its best efforts to remedy its
     inability to perform (this subsection shall not require the settlement of
     any strike, walkout, lockout or other labor dispute on terms which, in the
     sole judgment of the Party involved in the dispute, are contrary to its
     interest. It is understood and agreed that the settlement of strikes,
     walkouts, lockouts or other labor disputes shall be at the sole discretion
     of the Party having the difficulty),

                                      A-21
<PAGE>

          (4) when the non-performing Party is able to resume performance of its
     obligations under this Agreement, that Party shall give the other Party
     written notice to that effect, and
          (5) capacity payments during such periods of force majeure on Seller's
     part shall be governed by Section C-2(c) of Appendix C.

     (c) In the event a Party is unable to perform due to legislative, judicial,
or regulatory agency action, this Agreement shall be renegotiated to comply with
the legal change which caused the non-performance.

A-10 INDEMNITY

     Each Party as indemnitor shall save harmless and indemnify the other Party
and the directors, officers, and employees of such other Party against and from
any and all loss and liability for injuries to persons including employees of
either Party, and property damages including property of either Party resulting
from or arising out of (1) the engineering, design, construction, maintenance,
or operation of, or (2) the making of replacements, additions, or betterments
to, the indemnitor's facilities. This indemnity and save harmless provision
shall apply notwithstanding the active or passive negligence of the indemnitee.

                                      A-22
<PAGE>

Neither Party shall be indemnified hereunder for its liability or loss resulting
from its sole negligence or willful misconduct. The indemnitor shall, on the
other Party's request, defend any suit asserting a claim covered by this
indemnity and shall pay all costs, including reasonable attorney fees, that may
be incurred by the other Party in enforcing this indemnity.

     A-11 LIABILITY; DEDICATION

     (a) Nothing in this Agreement shall create any duty to, any standard of
care with reference to, or any liability to any person not a Party to it.
Neither Party shall be liable to the other Party for consequential damages.

     (b) Each Party shall be responsible for protecting its facilities from
possible damage by reason of electrical disturbances or faults caused by the
operation, faulty operation, or nonoperation of the other Party's facilities,
and such other Party shall not be liable for any such damages so caused.

     (c) No undertaking by one Party to the other under any provision of this
Agreement shall constitute the dedication of that Party's system or any portion
thereof to the other Party or to the public or affect the status of PGandE as an
independent public utility corporation or Seller as an independent individual or
entity and not a public utility.

                                      A-23
<PAGE>

A-12 SEVERAL OBLIGATIONS

     Except where specifically stated in this Agreement to be otherwise, the
duties, obligations, and liabilities of the Parties are intended to be several
and not joint or collective. Nothing contained in this Agreement shall ever be
construed to create an association, trust, partnership, or joint venture or
impose a trust or partnership duty, obligation, or liability on or with regard
to either Party. Each Party shall be liable individually and severally for its
own obligations under this Agreement.

A-13 NON-WAIVER

     Failure to enforce any right or obligation by either Party with respect to
any matter arising in connection with this Agreement shall not constitute a
waiver as to that matter or any other matter.

A-14 ASSIGNMENT

     Neither Party shall voluntarily assign its rights nor delegate its duties
under this Agreement, or any part of such rights or duties, without the written
consent of the other Party, except in connection with the sale or merger of a

                                      A-24
<PAGE>

substantial portion of its properties. Any such assignment or delegation made
without such written consent shall be null and void. Consent for assignment
shall not be withheld unreasonably. Such assignment shall include, unless
otherwise specified therein, all of Seller's rights to any refunds which might
become due under this Agreement.

A-15 CAPTIONS

     All indexes, titles, subject headings, section titles, and similar items
are provided for the purpose of reference and convenience and are not intended
to affect the meaning of the contents or scope of this Agreement.

A-15 CHOICE OF LAWS

     This Agreement shall be interpreted in accordance with the laws of the
State of California, excluding any choice of law rules which may direct the
application of the laws of another jurisdiction.

A-17 GOVERNMENTAL JURISDICTION AND AUTHORIZATION

     Seller shall obtain any governmental authorizations and permits required
for the construction and operation of the Facility. Seller shall reimburse
PGandE for any and all losses, damages, claims, penalties, or liability it

                                      A-25
<PAGE>

incurs as a result of Seller's failure to obtain or maintain such authorizations
and permits.

A-18 NOTICES

     Any notice, demand, or request required or permitted to be given by either
Party to the other, and any instrument required or permitted to be tendered or
delivered by either Party to the other, shall be in writing (except as provided
in Section C-3) and so given, tendered, or delivered, as the case may be, by
depositing the same in any United States Post Office with postage prepaid for
transmission by certified mail, return receipt requested, addressed to the
Party, or personally delivered to the Party, at the address in Article 4 of this
Agreement. Changes in such designation may be made by notice similarly given.

A-19 INSURANCE

A-19.1 General Liability Coverage

     (a) Seller shall maintain during the performance hereof, General Liability
Insurance(1) of not less than $1,000,000 if the Facility is over 100 kW,

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

1    Governmental agencies which have an established record of self- insurance
     may provide the required coverage through self-insurance.

                                      A-26
<PAGE>

$500,000 if the Facility is over 20 kW to 100 kW, and $100,000 if the Facility
is 20 kW or below of combined single limit or equivalent for bodily injury,
personal injury, and property damage as the result of any one occurrence.

     (b) General Liability Insurance shall include coverage for
Premises-Operations, Owners and Contractors Protective, Products/Completed
Operations Hazard, Explosion, Collapse, Underground, Contractual Liability, and
Broad Form Property Damage including Completed Operations.

     (c) Such insurance, by endorsement to the policy(ies), shall include PGandE
as an additional insured if the Facility is over 100 kw insofar as work
performed by Seller for PGandE is concerned, shall contain a severability of
interest clause, shall provide that PGandE shall not by reason of its inclusion
as an additional insured incur liability to the insurance carrier for payment of
premium for such insurance, and shall provide for 30-days' written notice to
PGandE prior to cancellation, termination, alteration, or material change of
such insurance.

A-19.2 Additional Insurance Provisions

     (a) Evidence of coverage described above in Section A-19.1 shall state that
coverage provided is primary and is not excess to or contributing with any
insurance or self-insurance maintained by PGandE.

                                      A-27
<PAGE>

     (b) PGandE shall have the right to inspect or obtain a copy of the original
policy(ies) of insurance.

     (c) Seller shall furnish the required certificates(1) and endorsements to
PGandE prior to commencing operation.

     (d) All insurance certificates(1), endorsements, cancellations,
terminations, alterations, and material changes of such insurance shall be
issued and submitted to the following:

        PACIFIC GAS AND ELECTRIC COMPANY
        Attention: Manager - Insurance Department
        77   Beale Street, Room E280
        San Francisco, CA  94106

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

1    A governmental agency qualifying to maintain self-insurance should provide
     a statement of self-insurance.

                                      A-28
<PAGE>

                                   APPENDIX B

                                  ENERGY PRICES
                                     TABLE A
               Energy Prices Effective August 1 - October 31, 1985

  The energy purchase price calculations which will apply to energy deliveries
   determined from meter readings taken during August, September, and October
                              1985 are as follows:

<TABLE>
<CAPTION>
                                (a)                 (b)                (c)                         (d)
                                                               Revenue Requirement           Energy Purchase
                           Incremental                               for Cash                    Price(4)
     Time Period          Energy Rate(1)     Cost of Energy(2)   Working Capital(3)       (d)=[(a) x (b)] + (c)
     -----------          --------------     -----------------   -----------------       ---------------------
                            (Btu/KWh)          ($/10(6) Btu)         ($/KWh)                   ($/KWh)
<S>                           <C>                <C>                  <C>                       <C>
August 1 - September 30
  (Period A)

  Time of
  Delivery Basis:

     On-Peak                  12,168             5.2445               0.00041                   0.06423
     Partial-Peak             11,369             5.2445               0.00038                   0.06000
     Off-Peak                  9,429             5.2445               0.00033                   0.04978

  Seasonal Average            10,515             5.2445               0.00036                   0.05551
     (Period A)

October 1 - October 31
    (Period 8)

  Time of
  Delivery Basis:

    On-Peak                   14,224             5.2445               0.00053                   0.07513
    Partial-Peak              13,552             5.2445               0.00051                   0.07158
    Off-Peak                  10,261             5.2445               0.00038                   0.05419

  Seasonal Average            11,954             5.2445               0.00045                   0 06314
    (Period B)
</TABLE>

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

1    Incremental energy rates (Btu/kwh) for Seasonal Period A and Seasonal
     Period B are derived from the marginal energy costs (including variable
     operating and maintenance expense) adopted by the CPUC in Decision No.
     83-12-068 (page 339). They are based upon natural gas as the incremental
     fuel and weighted average hydroelectric power conditions.

2    Cost of natural gas under PGandE Gas Schedule No. G-55 effective on August
     1, 1985.

3    Revenue Requirement for Cash Working Capital as prescribed by the CPUC in
     Decision No. 83-12-068.

4    Energy Purchase Price = (Incremental Energy Rate x Cost of Energy) +
     Revenue Requirement for Cash Working Capital. The energy purchase price
     excludes the applicable energy line loss adjustment factors. However, as
     ordered by Ordering Paragraph No. 12 (j) of CPUC Decision No. 82-12-120,
     this figure is currently 1.0 for transmission and primary distribution loss
     adjustments and is equal to marginal cost line loss adjustment factors for
     the secondary distribution voltage level. These factors may be changed by
     the CPUC in the future. The currently applicable energy loss adjustment
     factors are shown in Table C.

                                      B-1
<PAGE>

                                   TABLE B(1)
                                  Time Periods

<TABLE>
<CAPTION>
                                                     Monday
                                                     through                                  Sundays
                                                    Friday(2)            Saturdays(2)       and Holidays
                                                    ---------            ------------       ------------
<S>                                                  <C>                 <C>
      Seasonal Period A
(May 1 through September 30)

           On-Peak                                   12:30    p.m.
                                                           to
                                                      6:30    p.m.

           Partial-Peak                               8:30    a.m.       8:30    a.m.
                                                           to                 to
                                                     12:30    p.m.      10:30    p.m.

                                                      6:30    p.m.
                                                           to
                                                     10:30    p.m.

          Off-Peak                                   10:30    p.m.      10:30    p.m.           All Day
                                                           to                 to
                                                      8:30    a.m.       8:30    a.m.

      Seasonal Period B
(October 1 through April 30)

          On-Peak                                     4:30   p.m.
                                                           to
                                                      8:30   p.m.

          Partial-Peak                                8:30   p.m.        8:30    a.m.
                                                           to                to
                                                     10:30   p.m.       10:30    p.m.

                                                      8:30   a.m.
                                                          to
                                                      4:30   p.m.

          Off-Peak                                   10:30   p.m.       10:30    p.m.           All Day
                                                          to                 to
                                                      8:30   a.m.        8:30    a.m.
</TABLE>

1    This table is subject to change to accord with the on-peak, partial-peak,
     and off-peak periods as defined in PGandE's own rate schedules for the sale
     of electricity to its large industrial customers.
2    Except the following holidays: New Year's Day, Washington's Birthday,
     Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day,
     and Christmas Day, as specified in Public Law 90-363 (5 U.S.C.A. Section
     6103 (a)).

                                      B-2
<PAGE>

                                     TABLE C

                        Energy Loss Adjustment Factors(l)

<TABLE>
<CAPTION>

                                                           Primary         Secondary
                                        Transmission    Distribution     Distribution
                                        ------------    ------------     ------------
<S>                                         <C>             <C>             <C>
Seasonal Period A
    (May 1 through September 30)

       On-Peak                              1.0             1.0             1.0148
       Partial-Peak                         1.0             1.0             1.0131
       Off-Peak                             1.0             1.0             1.0093

Seasonal Period B
   (October 1 through April 30)

       On-Peak                              1.0             1.0             1.0128
       Partial-Peak                         1.0             1.0             1.0119
       Off-Peak                             1.0             1.0             1.0087
</TABLE>

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

1    The applicable energy loss adjustment factors may be revised pursuant to
     orders of the CPUC.

                                      B-3
<PAGE>

                                   APPENDIX C

                          FIRM CAPACITY PRICE SCHEDULE

                                    CONTENTS

Section                                                              Page
-------                                                              ----

  C-1      GENERAL                                                    C-2

  C-2      PERFORMANCE REQUIREMENTS                                   C-2

  C-3      SCHEDULED MAINTENANCE                                      C-5

  C-4      ADJUSTMENTS TO CONTRACT CAPACITY                           C-6

  C-5      PAYMENT OPTIONS                                            C-7

  C-6      DETERMINATION OF NATURAL FLOW DATA                         C-15

  C-7      THEORETICAL OPERATION STUDY                                C-16

  C-8      DETERMINATION OF AVERAGE DRY                               C-17
           YEAR CAPACITY RATINGS

  C-9      INFORMATION REQUIREMENTS                                   C-18

  C-10     ILLUSTRATIVE EXAMPLE                                       C-19

                                      C-1
<PAGE>

                                   APPENDIX C

                          FIRM CAPACITY PRICE SCHEDULE

C-1  GENERAL

     This Appendix C establishes conditions and prices under which PGandE shall
pay for firm capacity.

C-2  PERFORMANCE REQUIREMENTS

     (a) To receive full capacity payments the Facility must meet the following
requirements:

          (1) The contract capacity shall be available(1) for all of the on-peak
     hours(2) in the peak months on the PGandE system, which are presently the
     months of June, July, and August, subject to a 20 percent allowance for
     forced outages in any month. Compliance with this provision shall be based
     on the Facility's total on-peak availability(1) for each of the peak months
     and shall exclude any energy associated with generation levels greater than
     the contract capacity.

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

1    For purposes of Option I, "available" means either dispatchable by PGandE
     or actually delivered to PGandE_ For purposes of Option 2, "available"
     means actually delivered to PGandE.

2    On-peak, partial-peak, and off-peak hours are defined in Table B, Appendix
     B.

                                      C-2
<PAGE>

          (2) If Seller selects Option 1, the contract capacity shall be
     dispatchable throughout the year, subject to (i) a monthly allowance for
     forced outages of 20% of the hours Seller is called upon to deliver power
     to PGandE and (ii) the allowances for scheduled maintenance outages. Except
     during the peak months on the PGandE system, Seller may accumulate and
     apply the 20 percent allowance for forced outages for any consecutive three
     month period. Seller shall demonstrate that the Facility is fueled by a
     reliable fuel supply and adequate fuel storage is available to deliver
     power as requested by PGandE's system dispatcher. Such demonstration could
     reasonably include documentation of the current availability of the fuel,
     identification of the source, and production of contracts for its purchase
     and supply.

     (b) If Seller is prevented from meeting the performance requirements
because of a forced outage on the PGandE system or a condition set forth in
Section A-8, PGandE shall continue capacity payments. Under Option 2, capacity
payments will be calculated in the same manner used for scheduled maintenance
outages.

     (c) If Seller is prevented from meeting the performance requirements
because of force majeure, PGandE shall continue capacity payments for ninety
days from the occurrence of the force majeure. Thereafter, Seller shall be

                                      C-3
<PAGE>

deemed to have failed to have met the performance requirements. Under Option 2,
capacity payments will be calculated in the same manner used for scheduled
maintenance outages.

     (d) If Seller is prevented from meeting the performance requirements
because of exteme dry year conditions, PGandE shall continue capacity payments.
Extreme dry year conditions are drier than those used to' establish contract
capacity pursuant to Section C-8. Seller shall warrant to PGandE that the
Facility is a hydroelectric facility and that such conditions are the sole cause
of Seller's inability to meet its contract capacity obligations. Under Option 1,
starting with the month in which Seller cannot provide its contract capacity,
payments shall .be made under Option 2 for a one-year period, and if at the end
of this one-year period Seller is not able to resume the contract capacity due
solely to continued extreme dry year conditions, Seller shall continue to
receive payments under Option 2 for additional one-year periods as long as such
conditions continue to exist.

     (e) If Seller is prevented from meeting the performance requirements for
reasons other than those described above in Sections C-2(b), (c), or (d):
          (1) Seller shall receive the reduced capacity payments as provided in
     Section C-5 for a probationary period not to exceed15 months, or as
     otherwise agreed to by the Parties.

                                      C-4
<PAGE>

          (2) If, at the end of the probationary period Seller has not
     demonstrated that the Facility can meet the performance requirements,
     PGandE may derate the contract capacity pursuant to Section C-4(b).

C-3  SCHEDULED MAINTENANCE

     Outage periods for scheduled maintenance shall not exceed 840 hours (35
days) in any 12-month period. This allowance may be used in increments of an
hour or longer on a consecutive or nonconsecutive basis. Seller may accumulate
unused maintenance hours from one 12-month period to another up to a maximum of
1,080 hours (45 days). This accrued time must be used consecutively and only for
major overhauls. Seller shall provide PGandE with the following advance notices:
24 hours for scheduled outages less than one day, one week for a scheduled
outage of one day or more (except for major overhauls), and six months for a
major overhaul. Seller shall not schedule major overhauls during the peak months
(presently June, July and August). Seller shall make reasonable efforts to
schedule or reschedule routine maintenance outside the peak months, and in no
event shall outages for scheduled maintenance exceed 30 peak hours during the
peak months. Seller shall confirm in writing to PGandE pursuant to Article 4,
within 24 hours of the original notice, all notices Seller gives personally or
by telephone for scheduled maintenance.

                                      C-5
<PAGE>

C-4  ADJUSTMENTS TO CONTRACT CAPACITY

     (a) Seller may increase the contract capacity with the approval of PGandE
and receive payment for the additional capacity thereafter in accordance with
the applicable capacity purchase price published by PGandE at the time the
increase is first delivered to PGandE.

     (b) Seller may reduce the contract capacity at any time by giving notice
thereof to PGandE, subject to the provisions of Appendix D if the reduction
occurs after the actual operation date. PGandE may reduce the contract capacity
in accordance with Section C-2(e) as a result of appropriate data showing Seller
has failed to meet the performance requirements of Section C-2. The amount by
which the contract capacity is reduced by PGandE shall be deemed a capacity sale
reduction without notice as provided in Section D-3 of Appendix D.

     (c) Either Party may request, when it reasonably appears that the capacity
of the Facility may have changed for any reason, that a new contract capacity be
determined.

                                      C-6
<PAGE>

C-5  PAYMENT OPTIONS

     Seller has two options for calculation of capacity payments and Seller has
made its selection in Article 3(a). As used below in this section, month refers
to a calendar month. The two options are as follows:

                                    Option 1

     When Seller meets the requirements of Section C-2 the monthly payment for
capacity will be one-twelfth of the product of the contract cam price, the
contract capacity, the appropriate capacity loss adjustment factor from Table A
based on the Facility's interconnection voltage, and the appropriate performance
bonus factor, if any, from Table C. Capacity payments will continue during
scheduled maintenance outages provided that the provisions of Section C-3 are
met.

     During a probationary period Seller's monthly payment for capacity shall be
determined by substituting for the contract capacity, the capacity at which
Seller would have met the performance requirements. In any month during the
probationary period that Seller does not meet the performance requirements at
whatever capacity was determined for the previous month, Seller's monthly
payment for capacity shall be determined by substituting the capacity at which
Seller would have met the performance requirements.

                                      C-7
<PAGE>

The performance bonus factor shall not be applied during a probationary period.

                                    Option 2

     The monthly payment for capacity will be the product of the Period Price
Factor (PPF), the Monthly Delivered Capacity (MDC), the appropriate capacity
loss adjustment factor from Table A based on the Facility's interconnection
voltage, and the appropriate performance bonus factor, if any, from Table C,
plus any allowable payment for outages due to scheduled maintenance. Firm
capacity prices shall be applied to meter readings taken during the separate
times and periods as illustrated in Table B, Appendix B.

     The PPF is determined by multiplying the contract capacity price by the
following Option 2 Allocation Factors(1):

                              Option 2      x    Contract      =      PPF
                        Allocation Factor     Capacity Price      ($/kW-month)
                                              --------------
Seasonal
Period A                     .18540
                                              --------------      ------------
Seasonal
Period B                     .01043
                                              --------------      ------------

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

1    These allocation factors were prescribed by the CPUC in Decision No.
     83-12-068. All allocation factors are subject to change by PGandE based on
     PGandE's marginal capacity cost allocation, as determined in general rate
     case proceedings before the CPUC. Seasonal Periods A and B are defined in
     Table B. Appendix B.

                                      C-8
<PAGE>

The MDC is determined in the following manner:

     (1) Determine the Performance Factor (P), which is defined as the lesser of
1.0 or the following quantity:

                                     A                  (< or = 1.0)
                        P = --------------------
                            C x  (B-S) x  (0.8*)

Where:

A     =   Total kilowatt-hours delivered during all on-peak and partial-peak
          hours excluding any energy associated with generation levels greater
          than the contract capacity.
C     =   Contract capacity in kilowatts.
B     =   Total on-peak and partial-peak hours during the month.
S     =   Total on-peak and partial-peak hours during the month Facility is
          out of service on scheduled maintenance.

(2)  Determine the Monthly Capacity Factor (MCF which is computed using the
     following expression:

                                     M
                    MCF = P x (1.0 - -)
                                     D

Where:

M     =   The number of hours during the month Facility is out of service on
          scheduled maintenance.
D     =   The number of hours in the month.

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

* 0.8 reflects a 20% allowance for forced outage.

                                      C-9
<PAGE>

     (3)  Determine the MDC by multiplying the MCF by C:

                    MDC  (kilowatts) = MCF x C

     The monthly payment for capacity is then determined by multiplying the PPF
by the MDC, by the appropriate capacity loss adjustment factor presented from
Table A, and by the appropriate performance bonus factor, if any, from Table C.

monthly payment   =   PPF   x   MDC   x     capacity loss     x  performance
for capacity                              adjustment factor      bonus factor

     Furthermore, the payment for a month in which there is an outage for
scheduled maintenance shall also include an amount equal to the product of the
average hourly capacity payment(1) for the most recent month in the same type of
Seasonal Period (i.e., Seasonal Period A or Seasonal Period B) during which
deliveries were made times the number of hours of outage for scheduled
maintenance in the current month. Capacity payments will continue during the
outage periods for scheduled maintenance provided that the provisions of section
C-3 are met.

     During a probationary period Seller's monthly payment for capacity shall be
determined by substituting for the contract capacity, the capacity at which

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

1    Total monthly payment divided by the total number of hours in the monthly
     billing period.

                                      C-10
<PAGE>

Seller would have met the performance requirements. In the event that during the
probationary period Seller does not meet the performance requirements at
whatever capacity was established for the previous month, Seller's monthly
payment for capacity shall be determined by substituting the capacity at which
Seller would have met the performance requirements. The performance bonus factor
shall not be applied during probationary periods.

                                     TABLE A

If the Facility is non-remote(1) the capacity loss adjustment factors are as
follows:

                                                               Capacity Loss
Interconnection Voltage                                      Adjustment Factor
-----------------------                                      -----------------

Transmission                                                        .989

Primary Distribution                                                .991

Secondary Distribution                                              .991

If the Facility is remote the capacity loss adjustment
factor is ________________ (2)

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

1    As defined by the CFUC.

2    The Seller acknowledges that this blank cannot be filled in at the time of
     executing the Agreement because the information is not yet available to
     make a definitive determination of whether the Facility is remote or
     non-remote and, if remote, the number to be inserted in this blank. Seller
     shall request PGandE to perform a capacity loss adjustment factor study to
     be done in its accustomed manner of making such studies to determine
     whether the Facility is remote or non-remote and, if remote, the number to
     be inserted. If the Facility is determined to be non-remote, "N/A" shall be
     inserted.

                                      C-11
<PAGE>

                                     TABLE B

                          Firm Capacity Price Schedule
                          ----------------------------

                             (Levelized $/kW-year)

<TABLE>
<CAPTION>
 Actual
Operation
  Date                                                 Term of Agreement
  ----                                                 -----------------

Year          1     2     3     4     5     6     7     8     9    10    11    12    13    14    15    20    25    30
----          -     -     -     -     -     -     -     -     -    --    --    --    --    --    --    --    --    --
<S>          <C>  <C>    <C>   <C>   <C>   <C>   <C>   <C>   <C>   <C>   <C>  <C>   <C>   <C>   <C>   <C>   <C>   <C>
1983         72   111    96    88    84    85    88    91    93    96    98   100   102   104   106   115   122   128
1984        156   111    95    88    89    92    95    98   100   103   105   108   110   112   114   124   131   137

1985         60    58    59    66    73    79    84    88    92    95    99   102   104   107   110   120   129   135
1986         56    58    69    78    85    90    95    99   103   106   110   113   116   118   121   132   141   148

1987         61    77    88    95   10.1  105   109   113   117   120   124   127   130   132   135   147   156   163
1988         96   104   110   114   119   122   126   129   133   136   139   142   145   148   151   163   173   180
</TABLE>

                                      C-12
<PAGE>

                                     TABLE C

                            Performance Bonus Factor

     The following shall be the performance bonus factors applicable to the
calculation of the monthly payments for capacity delivered by the Facility after
it has demonstrated a capacity factor in excess of 85%.

                     DEMONSTRATED
                    CAPACITY FACTOR               PERFORMANCE
                          (%)                    BONUS FACTOR
                    ------------------------------------------

                           85                        1.000
                           90                        1.059
                           95                        1.118
                          100                        1.176

     After the Facility has delivered power during the span of all of the peak
months on the PGandE system (presently June, July, and August) in any year
(span),

     (1) the capacity factor for each such month shall be calculated in the
following manner:

                                              F
           CAPACITY FACTOR (%)  =  ----------------------- x 100
                                           (N-W) x Q

Where:

                                  For Option 1
                                  ------------

     F =  Total kilowatt-hours delivered by Seller in any peak month
          during all on-peak hours that Seller is asked to deliver power

                                      C-13
<PAGE>

          to PGandE excluding any energy associated with generation levels
          greater than the contract capacity.
     N =  Total on-peak hours that Seller is asked to deliver power to PGandE
          during the month.
     W =  Total on-peak hours during the peak month that the Facility is out
          of service on scheduled maintenance during the on-peak hours that
          Seller is asked to deliver power to PGandE.
     Q =  Contract capacity in kilowatts.

                                  For Option 2
                                  ------------

     F =  Total kilowatt-hours delivered by Seller in any peak month during
          all on-peak hours excluding any energy associated with generation
          levels greater than the contract capacity.
     N =  Total on-peak hours during the month.
     W =  Total on-peak hours during the peak month that the Facility is out
          of service on scheduled maintenance.
     Q =  Contract capacity in kilowatts.

     (ii) the arithmetic average of the above capacity factors shall be
determined for that span,

     (iii) the average of the above arithmetic average capacity factors for the
most recent span(s), not to exceed 5, shall be calculated and shall become the
Demonstrated Capacity Factor.

                                      C-14
<PAGE>

     To calculate the performance bonus factor for a Demonstrated Capacity
Factor not shown in Table D use the following formula:

Performance Bonus Factor = Demonstrated Capacity Factor (%)
                           --------------------------------
                                         85%

THE FOLLOWING SECTIONS SHALL APPLY ONLY TO HYDROELECTRIC PROJECTS
-----------------------------------------------------------------

C-6  DETERMINATION OF NATURAL FLOW DATA

     Natural flow data shall be based on a period of record of at least 50 years
and which includes historic critically dry periods. In the event Seller
demonstrates that a natural flow data base of at least 50 years would be
unreasonably burdensome, PGandE shall accept a shorter period of record with a
corresponding reduction in the averaging basis set forth in Section C-8. Seller
shall determine the natural flow data by month by using one of the following
methods:

                                    Method 1

     If stream flow records are available from a recognized gauging station on
the water course being developed in the general vicinity of the project, Seller
may use the data from them directly.

                                      C-15
<PAGE>

                                    Method 2

     If directly applicable flow records are not available, Seller may develop
theoretical natural flows based on correlation with available flow data for the
closest adjacent and similar area which has a recognized gauging station using
generally accepted hydrologic estimating methods.

C-7  THEORETICAL OPERATION STUDY

     Based on the monthly natural flow data developed under section C-6 a
theoretical operation study shall be prepared by Seller. Such a study shall
identify the monthly capacity rating in kW and the monthly energy production in
kWh for each month of each year. The study shall take into account all relevant
operating constraints, limitations, and requirements including but not limited
to --
     (1) Release requirements for support of fish life and any other operating
constraints imposed on the project;
     (2) Operating characteristics of the proposed equipment of the Facility
such as efficiencies, minimum and maximum operating levels, project control
procedures, etc.;

                                      C-16
<PAGE>

     (3) The design characteristics of project facilities such as head losses in
penstocks, valves, tailwater elevation levels, etc.; and
     (4) Release requirements for purposes other than power generation such as
irrigation, domestic water supply, etc.

     The theoretical operation study for each month shall assume an even
distribution of generation throughout the month unless Seller can demonstrate
that the Facility has water storage characteristics. For the study to show
monthly capacity ratings, the Facility shall be capable of operating during all
on-peak hours in the peak months on the PGandE system, which are presently the
months of June, July, and August. If the project does not have this capability
throughout each such month, the capacity rating in that month of that year shall
be set at zero for purposes of this theoretical operation study.

C-8  DETERMINATION OF AVERAGE DRY YEAR CAPACITY RATINGS

     Based on the results of the theoretical operation study developed under
Section C-7, the average dry year capacity rating shall be established for each
month. The average dry year shall be based on the average of the five years of
the lowest annual generation as shown in the theoretical operation study. Once
such years of lowest annual generation are identified, the monthly capacity
rating is determined for each month by averaging the capacity ratings from each

                                      C-17
<PAGE>

month of those years. The contract capacity shown in Article 2(a) shall not
exceed the lowest average dry year monthly capacity ratings for the peak months
on the PGandE system, which are presently the months of June, July, and August.

C-9  INFORMATION REQUIREMENTS

     Seller shall provide the following information to PGandE for its review:
     (1) A summary of the average dry year capacity ratings based on the
theoretical operation study as provided in Table D;
     (2) A topographic project map which shows the location of all aspects of
the Facility and locations of stream gauging stations used to determine natural
flow data;
     (3) A discussion of all major factors relevant to project operation;
     (4) A discussion of the methods and procedures used to. establish the
natural flow data. This discussion shall be in sufficient detail for PGandE to
determine that the methods are consistent with those outlined in Section C-6 and
are consistent with generally accepted engineering practices; and
     (5) Upon specific written request by PGandE, Seller's theoretical operation
study.

                                      C-18
<PAGE>

C-10 ILLUSTRATIVE EXAMPLE

     (1) Determine natural flows - These flows are developed based on historic
stream gauging records and are compiled by month, for a long-term period
(normally at least 50 years or more) which covers dry periods which historically
occurred in the 1920's and 30's and more recently in 1976 and 77. In all but
unusual situations this will require application of hydrological engineering
methods to records that are available, primarily from the USGS publication
"Water Resources Data for California".

     (2) Perform theoretical operation study - Using the natural flow data
compiled under (1) above a theoretical operation study is prepared which
determines, for each month of each year, energy generation (kWh) and capacity
rating (kW). This study is performed based on the Facility's design, operating
capabilities, constraints, etc., and should take into account all factors
relevant to project operation. Generally such a study is done by computer which
routes the natural flows through project features, considering additions and
withdrawals from storage, spill past the project, releases for support of fish
life, etc., to determine flow available for generation. Then the generation and
capacity amounts are computed based on equipment performance, efficiencies, etc.

                                      C-19
<PAGE>

     (3) Determine average dry year capacity ratings After the theoretical
project operation study is complete the five years in which the annual
generation (kWh) would have been the lowest are identified. Then for each month,
the capacity rating (kW) is averaged for the five years to arrive at a monthly
average capacity rating. The contract capacity is then set by the Seller based
on the monthly average dry year capacity ratings and the performance
requirements of Appendix C. An example project is shown in the attached
completed Table D.

                                      C-20
<PAGE>

                                     EXAMPLE
                                     -------

                                     TABLE D

                     Summary of Theoretical Operation Study

Project: New Creek 1                         Dispatchable: Yes ___ No X

Water Source: West Fork New Creek

Mode of Operation: Run of the river

Type of Turbine: Francis        Design Flow:  100 cfs     Design Head: 150 feet

Operating Characteristics(1):

                       Flow       Head (feet)     Output      Efficiency (%)
                      (cfs)      Gross   Net       (kW)     Turbine   Generator
                      -----      -----   ---       ----     -------   ---------

Normal Operation       100        160    150      1,120        90         98
Maximum Operation      110        160    148      1,150        85         98
Minimum Operation       30        160    155        290        75         98

Average Dry Year Operation - Based on the average of the following lowest
generation years: 1930, 1932, 1934, 1949, 1977.

                 Energy Generation    Capacity Output         Percent of
 Month                (kWh)                (kW)          Total Hours Operated(2)
 -----                -----                ----          ----------------------

January              855,000               1,150                  100
February             753,000               1,120                  100
March                818,000               1,100                  100
April                727,000               1,010                  100
May                  699,000                 940                  100
June                 612,000                 850                  100
July                 484,000                 650                  100
August               305,000                 410                  100
September            245,000                 340                  100
October              148,800                 200                  100
November             468,000                 650                  100
December             595,000                 800                  100

Maximum Contract Capacity:   410 kW

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

1    If Facility has a variable head, operating curves should be provided.

2    For this to be less than 100%, Facility must be dispatchable.

                                      C-21
<PAGE>

                                   APPENDIX D

                         ADJUSTMENT OF CAPACITY PAYMENTS
                    IN THE EVENT OF TERMINATION OR REDUCTION

                                    CONTENTS

Section                                                                   Page
-------                                                                   ----

D-1       GENERAL PROVISIONS                                               D-2

D-2       TERMINATION WITH PRESCRIBED NOTICE                               D-4

D-3       TERMINATION WITHOUT PRESCRIBED NOTICE                            D-5

D-4       TERMINATION EXAMPLES                                             D-6

                                      D-1
<PAGE>

                                   APPENDIX D

                         ADJUSTMENT OF CAPACITY PAYMENTS

                    IN THE EVENT OF TERMINATION OR REDUCTION

D-1  GENERAL PROVISIONS

     (a) This Appendix shall be applicable in the event there is a contract
termination or a capacity sale reduction (each sometimes referred to as
"termination" in this Appendix D).

     (b) The Parties agree that the amount which PGandE pays Seller for the
capacity which Seller makes available to PGandE is based on the agreed value to
PGandE of Seller's performance of capacity obligations during the full period of
the term of agreement. The Parties further agree that in the event PGandE does
not receive such full performance by reason of a termination:
          (1) PGandE shall be deemed damaged by reason thereof,
          (2) it would be impracticable or extremely difficult to fix the actual
     damages to PGandE resulting therefrom,
          (3) the refunds and payments as provided in Sections D-2 and D-3, as
     applicable, are in the nature of adjustments in capacity prices and

                                      D-2
<PAGE>

     liquidated damages, and not a penalty, and are fair and reasonable, and
          (4) such refunds and payments represent a reasonable endeavor by the
     Parties to estimate a fair compensation for the reasonable losses that
     would result from such termination or reduction.

     (c) In the event of a capacity sale reduction, the quantity by which the
contract capacity is reduced shall be used to calculate the payments due PGandE
in accordance with Sections D-2 and D-3, as applicable.

     (d) Seller shall be invoiced by PGandE for all refunds and payments due
under this Appendix D and the special facilities agreement. From the date of the
notice of termination or the date of termination, whichever is earlier, Seller
shall pay interest, compounded monthly, on all overdue amounts, at the published
Federal Reserve Board three months' Prime Commercial Paper rate.

     (e) If Seller does not make payments pursuant to Section D-1(d), PGandE
shall have the right to offset any amounts due it against any present or future
payments due Seller.

     (f) Notices of termination shall be made in accordance with Section A-l8 of
Appendix A.

                                      D-3
<PAGE>

D-2  TERMINATION WITH PRESCRIBED NOTICE

     In the event Seller terminates this entire Agreement, or all or part of the
contract capacity thereof, with the following prescribed written notice:

          Amount of Contract Capacity                        Length of
                 Termiminated                             Notice Required
                 ------------                             ---------------

          1,000 kW or under                                    3  months
          over   1,000 kW through  10,000 kW                   9  months
          over  10,000 kW through  25,000 kW                  12  months
          over  25,000 kW through  50,000 kW                  36  months
          over  50,000 kW through 100,000 kW                  48  months
          over 100,000 kW                                     60  months

Then the following provisions shall apply:
     (1) With respect to the amount by which the contract capacity is reduced,
Seller shall refund to PGandE an amount equal to the difference between (a) the
capacity payments already paid by PGandE, based on the original term of
agreement and (b) the total capacity payments which PGandE would have paid based
on the period of Seller's actual performance using the adjusted capacity price.
Additionally, Seller shall pay interest, compounded monthly, on all
overpayments, at the published Federal Reserve Board three months' Prime
Commercial Paper rate.
     (2) From the date PGandE receives the termination notice to the date of
actual termination, PGandE shall make capacity payments based on the adjusted
capacity price for the amount of contract capacity being terminated.

                                      D-4
<PAGE>

     (3) From the date PGandE receives the termination notice, PGandE shall
continue to pay for the amount of contract capacity not being terminated, if
any, at the original contract capacity price.

D-3  TERMINATION WITHOUT PRESCRIBED NOTICE

     (a) If Seller terminates this Agreement, or all or a part of the contract
capacity thereof, without the notice prescribed in Section D-2, the provisions
prescribed in Section D-2 will all apply. Additionally:

     (b) Seller shall pay PGandE a sum equal to the amount by which the contract
capacity is being terminated times the difference between the current firm
capacity price on the date of termination for a term equal to the balance of the
term of agreement and the contract capacity price, pro-rated for the length of
notice given by multiplying by the difference between the prescribed length of
notice and the actual notice given, with the difference divided by 12. In the
event that the current firm capacity price is less than the contract capacity
price, no payment under this Section D-3 shall be due either Party.
     This additional payment shall be computed using the following formula:

                                                 J - H
                            G = CC x (T - CCP) x -----
                                                  12

                                      D-5
<PAGE>

Where G >/= 0

and where:

G   =  additional payment.

CC  =  the amount by which the contract capacity is being terminated.

T   =  the current firm capacity price.

CCP =  the contract capacity price.

H   =  the actual number of months notice given.

J   =  the prescribed length of notice.

D-4  TERMINATION EXAMPLES

     These examples demonstrate how to calculate capacity payment adjustments
when capacity sales are terminated.

(a)  Termination with Prescribed Notice
     (1)  Example Based on option 1
          Assumptions:
          i.   Term of agreement is 15 years;
          ii.  Actual operation date is July 1, 1985;
          iii. Prescribed notice is given on July 1, 1.986;

                                      D-6
<PAGE>

          iv.  Contract capacity to be reduced by 10,000 kW on July 1, 1987;
               actual performance to be from July 1, 1985 through July 1,
               1987(1);
          v.   The applicable capacity loss adjustment factor is 989; and
          vi.  No performance bonus for capacity has been earned.

          The amount of overpayment (E) made by PGandE to Seller during each
     monthly billing period is calculated as follows:

                                  E = (A - B) x C x L x U

     Where:

     A =  contract capacity price per month for the actual operation date
          (July 1, 1985) and the term of agreement which is 15 years =
          $110/kW-yr / 12mo/yr = $9.17/kW-mo.
     B =  adjusted capacity price per month for the actual operation date
          (July 1, 1984) and a two-year agreement term = $58/kW-yr / 12 mo/yr =
          $4.83/kW-mo.

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

1    The capacity payment is adjusted upon receiving notice, so no refund is
     necessary for the last month of the first twelve months of operation and
     all of the second twelve months (June 1, 1986 to July 1, 1987). Seller
     performed for eleven months prior to payment adjustment. (Note that due to
     the 30-day interval between delivery and payment, performance in the
     twelfth month (June 1986) can be paid for at the adjusted capacity price.

                                      D-7
<PAGE>

     C =  amount by which the contract capacity- is being reduced = 10,000 kW.
     L =  capacity loss adjustment factor = .989.
     U =  performance bonus factor; when Seller does not qualify for a
          performance bonus factor, as in this example, U is removed from the
          above calculation of E.
     Therefore:
     E =  ($9.17/kW-mo - $4.83/kW-mo) x 10,000 kW x .989 = $42,923 per month.

          Table A shows a step-by-step derivation of the refund Seller owes
     PGandE for the early termination outlined above. The $497,342 that Seller
     owes PGandE appears at the lower right-hand corner of the table. All other
     figures of this table represent intermediate calculation steps.

                                      D-8
<PAGE>

                                     TABLE A
<TABLE>
<CAPTION>
  (a)           (b)            (c)           (D)           (E)             (f)                  (g)
  ---           ---            ---           ---           ---             ---                  ---
                                                                        Interest
                             Amount         Accumu-                   Charge(6) on
Monthly                       of            lated                      Accumulated           Balance(7)
Billing      Date of         Over-          Over-       Interest       Overpayment              (g)=
Period(1)    Payment(2)    Payment(3)     Payment(4)     Rate(5)       (f)=(d)x(e)          (c)+(d)+(f)
---------    ----------    ----------     ----------     -------       -----------          -----------
  <S>        <C>             <C>          <C>             <C>             <C>                <C>
                                $             $            %                $                    $
   7/85       8/30/85        42,923             0         1.2                 0               42,923
   8/85       9/30/85        42,923        42,923         1.0               429               86,275
   9/85      10/30/85        42,923        86,275         0.9               776              129,974
  10/85      11/30/85        42,923       129,974         0.8             1,040              173,937
  11/85      12/30/85        42,923       173,937         0.7             1,218              218,078
  12/85       1/30/86        42,923       218,078         0.8             1,745              262,746
   1/86        3/2/86        42,923       262,746         0.9             2,365              308,034
   2/86       3/30/86        42,923       308,034         1.0             3,080              354,037
   3/86       4/30/86        42,923       354,037         1.1             3,894              400,854
   4/86       5/30/86        42,923       400,854         1.2             4,810              448,587
   5/86       6/30/86        42,923       448,587         1.3             5,832              497,342
                                                                                             ========
</TABLE>

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

1    The month in which power deliveries were made. For purposes of
     simplification, the monthly billing period will coincide exactly with each
     calendar month.

2    The date on which payment for the monthly billing period stated in column
     (a) is made.

3    The amount of overpayment made by PGandE to Seller during each monthly
     billing period.

4    The amount of overpayment accumulated up through last month's date of
     payment.

5    The interest rate for the period between the date of payment for the
     previous monthly billing period and the date of payment for this monthly
     billing period. These interest rates are arbitrarily chosen for use in this
     example.

6    the- amount of interest charge accrued between the. date, of) payment for
     the previous monthly billing period and the date of payment for this
     monthly billing period on the accumulated overpayment balance existing as
     of the previous monthly billing period's date of payment.

7    The amount Seller owes PGandE at this stage of the calculation. The balance
     (g) for a given monthly billing period equals the accumulated overpayment
     (d) for the monthly billing period immediately following.

                                      D-9
<PAGE>

          (2)  Example Based on Option 2
               Assumptions:
               i.   Term of agreement is 15 years;
               ii.  Actual operation date is April 1, 1985;
               iii. Prescribed notice is given on April 1, 1987;
               iv.  Contract capacity is reduced by 10,000 kW on April 1, 1988;
                    actual performance is from April 1, 1985 through April 1,
                    1988(1);
               v.   Scheduled outage for maintenance: 18 days = 432 hours in
                    both November 1985 and November 1986;
               vi.  The applicable capacity loss adjustment factor is 989; and
               vii. Listed below is Seller's Performance Factor (P), the
                    Demonstrated Capacity Factor (Y) in % (when measured), and
                    where applicable, the performance bonus factor (U) earned
                    for each of the monthly billing periods(2) prior to the time
                    capacity payment is adjusted. Also listed below are the
                    number of hours

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

1    The capacity payment is adjusted upon receiving notice, so no refund is
     necessary for the last month of the first twenty-four months of operation
     and all of the last twelve months (March 1, 1987 to April 1, 1988). Seller
     performed for twenty-three months prior to payment adjustment. [Note that
     due to the 30-day interval between delivery and payment, performance in the
     twenty-fourth month (March 1987) can be paid for at the adjusted capacity
     price.]

2    For purposes of simplification, the monthly billing period will coincide
     exactly with each calendar month.

                                      D-10
<PAGE>

                    the Facility was out of service for scheduled maintenance
                    (M) and the number of hours in the month (D) for each of
                    these months.

<TABLE>
<CAPTION>
Monthly Billing Period                      P             Y          U             M        D
----------------------                      -             -          -             -        -
<S>                       <C>             <C>            <C>      <C>            <C>      <C>
April                     1985             .85            -          -             0      720
May                       1985             .95            -          -             0      744
June                      1985             .90           80          -             0      720
July                      1985            1.00           88          -             0      744
August                    1985             .90           96          -             0      744
September                 1985            1.00            -       1.035*           0      720
October                   1985             .96            -       1.035            0      744
November                  1985             .98            -       1.035          432      720
December                  1985            1.00            -       1.035            0      744
January                   1986            1.00            -       1.035            0      744
February                  1986             .92            -       1.035            0      672
March                     1986             .85            -       1.035            0      744
April                     1986             .78            -       1.035            0      720
May                       1986            1.00            -       1.035            0      744
June                      1986             .94          100       1.035            0      720
July                      1986             .95           95       1.035            0      744
August                    1986            1.00           92       1.035            0      744
September                 1986            1.00            -       1.080**          0      720
October                   1986             .93            -       1.080            0      744
November                  1986             .84            -       1.080          432      720
December                  1986             .88            -       1.080            0      744
January                   1987             .94            -       1.080            0      744
February                  1987            1.00            -       1.080            0      672
</TABLE>

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

*    This performance bonus factor was calculated by averaging the Demonstrated
     Capacity Factors for each of the months of June, July, and August 1985, and
     then dividing that average by 85(%):

                            80 + 88 + 96
                       U =  ------------  / 85  = 1.035
                                 3

**   This performance bonus factor was calculated by averaging the Demonstrated
     Capacity Factors for each. of the months of June, July, and August 1985,
     and June, July, and August 1986, and then dividing that average by 85(%):

                            80 + 88 + 96 + 100 + 95 + 92
                       U =  ----------------------------  / 85 = 1.080
                                           6

                                      D-11
<PAGE>

          The amount of overpayment (E) made by PGandE to Seller during each
     monthly billing period is calculated as follows:

                               M                                M
               E  =  [P x (1 - -) x K x L x U x (A - B) x C] + [- x R]
                               D                                D

     Where:
     P =  performance factor.
     M =  number of hours of scheduled maintenance for that monthly billing
          period.
     D =  number of hours in that monthly billing period.
     K =  allocation factor from Section C-5.
     L =  capacity loss adjustment factor = .989.
     U =  performance bonus factor; when Seller does not qualify for a
          performance bonus factor, U is removed from the above calculation of
          E.
     A =  Contract capacity price for the actual operation date (April 1,
          1985) and term of agreement which is 15 years = $110/kW-yr.
     B =  adjusted capacity price for the actual operation date and a
          three-year agreement term = $59/kW-yr.
     C =  amount by which the contract capacity is being reduced = 10,000 kW.

                                      D-12
<PAGE>

     R =  amount of overpayment for the most recent monthly billing period in
          the same Seasonal Period (i.e., Seasonal Period A or Seasonal Period
          B).

     The results of the calculations are:

                                                                    Amount of
     Monthly Billing Period                                      Overpayment (E)
     ----------------------                                      ---------------

     April                         1985                          $    4,472
     May                           1985                              88,838
     June                          1985                              84,163
     July                          1985                              93,514
     August                        1985                              84,163
     September                     1985                              96,787
     October                       1985                               5,227
     November                      1985                               5,271
     December                      1985                               5,445
     January                       1986                               5,445
     February                      1986                               5,009
     March                         1986                               4,628
     April                         1986                               4,247
     May                           1986                              96,787
     June                          1986                              90,980
     July                          1986                              91,948
     August                        1986                              96,787
     September                     1986                             100,995
     October                       1986                               5,284
     November                      1986                               5,079
     December                      1986                               5,000
     January                       1987                               5,341
     February                      1987                               5,682

          Table B shows a step-by-step derivation of the refund Seller owes
     PGandE for the early termination outlined above. The $1,136,015 that Seller
     owes PGandE appears at the lower right-hand corner of the table. All other
     figures of this table represent intermediate calculation steps.

                                      D-13
<PAGE>

<TABLE>
<CAPTION>
                                     TABLE B

 (a)            (b)            (c)           (d}            (e)             (f)              (g)
 ---            ---            ---           ---            ---             ---              ---
                                                                            Interest
                              Amount        Accumu-                      Charge(6) on
Monthly                         of          lated                         Accumulated     Balance(7)
Billing       Date of          Over-        Over-          Interest       Overpayment        (g)=
Period(1)    Payment(2)     Payment(3)    Payment(4)       Rate(5)        (f)=(d)x(e)    (c)+(d)+(f)
---------    ----------     ----------    ----------       -------        -----------    -----------
                                 $             $              %               $               $
<S>           <C>             <C>           <C>             <C>             <C>         <C>
 4/85          5/30/85         4,472              0         1.3                 0           4,472
 5/85          6/30/85        88,838          4,472         1.4                63          93,373
 6/85          7/30/85        84,163         93,373         1.3             1,214         178,750
 7/85          8/30/85        93,514        178,750         1.2             2,145         274,409
 8/85          9/30/85        84,163        274,409         1.0             2,744         361,316
 9/85         10/30/85        96,787        361,316         0.9             3,252         461,355
10/85         11/30/85         5,227        461,355         0.8             3,691         470,273
11/85         12/30/85         5,271        470,273         0.7             3,292         478,836
12/85          1/30/86         5,445        478,836         0.8             3,831         488,112
 1/86           3/2/86         5,445        488,112         0.9             4,393         497,950
 2/86          3/30/86         5,009        497,950         1.0             4,980         507,939
 3/86          4/30/86         4,628        507,939         1.1             5,587         518,154
 4/86          5/30/86         4,247        518,154         1.2             6,218         528,619
 5/86          6/30/86        96,787        528,619         1.3             6,872         632,278
 6/86          7/30/86        90,980        632,278         1.4             8,852         732,110
 7/86          8/30/86        91,948        732,110         1.4            10,250         834,308
 8/86          9/30/86        96,787        834,308         1.3            10,846         941,941
 9/86         10/30/86       100,995        941,941         1.2            11,303       1,054,239
10/86         11/30/86         5,284      1,054,239         1.0            10,542       1,070,065
11/86         12/30/86         5,079      1,070,065         1.1            11,771       1,086,915
12/86          1/30/87         5,000      1,086,915         1.1            11,956       1,103,871
 1/87           3/2/87         5,341      1,103,871         1.0            11,039       1,120,251
 2/87          3/30/87         5,682      1,120,251         0.9            10,082       1,136,015
                                                                                        =========
</TABLE>

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

1    The month in which power deliveries were made. For purposes of
     simplification, the monthly billing period will coincide exactly with each
     calendar month.
2    The date on which payment for the monthly billing period stated in column
     (a) is made.
3    The amount of overpayment made by PGandE to Seller during each monthly
     billing period.
4    The amount of overpayment accumulated up through last month's date of
     payment.
5    The interest rate for the period between the date of payment for the
     previous monthly billing period and the date of payment for this monthly
     billing period. These interest rates are arbitrarily chosen for use in this
     example.
6    The amount of interest charge accrued between the date of payment for the
     previous monthly billing period and the date of payment for this monthly
     billing period on the accumulated overpayment balance existing as of the
     previous monthly billing period's date of payment.
7    The amount Seller owes PGandE at this stage of the calculation. The balance
     (g) for a given monthly billing period equals the accumulated overpayment
     (d) for the monthly billing period immediately following.

                                      D-14
<PAGE>

(b)  Termination without Prescribed Notice
     If Seller terminates without prescribed notice, Seller will owe PGandE a
refund [the calculation of which is described in Sections D-4(a)(1) and
D-4(a)(2) of this example] and payment (G). This example demonstrates how the
payment (G) is calculated. Assumptions:
     i.   Term of agreement is 15 years;
     ii.  Actual operation date is July 1, 1985;
     iii. Notice is given on January 1, 1990; and
     iv.  Contract capacity is to be reduced by 10,000 kW on July 1, 1990;
          actual performance is from July 1, 1985 through July 1, 1990.

     The payment (G) is calculated as follows:

                                  J-H
           G  = CC x (T - CCP) x (---)        G > or = 0
                                   12

     Where:

     CC = The amount of contract capacity being terminated = 10,000 kW.
     T  = the current firm capacity price $140/kW-yr is arbitrarily chosen for
          use in this example for a July 1, 1990 Operation Date and 10-year
          agreement term.
     CCP= the contract capacity price = $110/kW-yr.
     H  = the actual number of months notice given = six months.
     J  = the prescribed notice = twelve months.

                                      D-15
<PAGE>

     The sample calculation is.

                            J-H
     G  = CC x (T - CCP) x (---)
                             12

     G  = 10,000 kW x ($140/kW-yr - $110/kW-yr) x

                 22 mos. -  6 mos.
                (-----------------)
                    (12 mos./yr

     G  = $150,000
          ========

                                      D-16
<PAGE>

                                   APPENDIX E

                                 INTERCONNECTION

                                    CONTENTS

Section                                                                  Page
-------                                                                  ----

   E-1               INTERCONNECTION TARIFFS                             E-2

   E-2               POINT OF DELIVERY LOCATION SKETCH                   E-3

   E-3               INTERCONNECTION FACILITIES FOR WHICH                E-4
                     SELLER IS RESPONSIBLE

                                      E-1
<PAGE>

E-1  INTERCONNECTION TARIFFS

     The applicable tariff follows on the succeeding pages.

                                      E-2
<PAGE>

Pacific Gas and Electric Company            Revised Cal. P.U.C. Sheet No. 8616-E
   San Francisco. California    Cancelling Original Cal. P.U.C. Sheet No. 7693-E
--------------------------------------------------------------------------------
               RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION

This describes the minimum operation, metering and interconnection requirements
for any generating source or sources paralleled with the Utility's electric
system. Such source or sources may include, but are not limited to,
hydroelectric generators, wind-turbine generators, steam or gas driven turbine
generators and photovoltaic systems.

A.   GENERAL

     1.   The type of interconnection and voltage available at any location and
          the Utility's specific interconnection requirements shall be
          determined by inquiry at the Utility's local office.

     2.   The Utility's distribution and transmission lines which are an
          integral part of its overall system are distinguished by the voltages
          at which they are operated. Distribution lines are operated at
          voltages below 60 kv and transmission lines are operated at voltages
          60 kv and higher.

     3.   The Power Producer (Producer) shall ascertain and be responsible for
          compliance with the requirements of all governmental authorities
          having jurisdiction.

     4.   The Producer shall sign the Utility's written form of power purchase
          agreement or parallel operation agreement before connecting or
          operating a generating source in parallel with the Utility's system.

     5.   The Producer shall be fully responsible for the costs of designing,
          installing, owning, operating and maintaining all interconnection
          facilities defined in Section B.1.

     6.   The Producer shall submit to the Utility, for the Utility's review and
          written acceptance, equipment specifications and detailed plans for
          the installation of all interconnection facilities to be furnished by
          the Producer prior to their purchase or installation. The Utility's
          review and written acceptance of the Producer's equipment
          specifications and detailed plans shall not be construed as confirming
          or endorsing the Producer's design or as warranting the equipment's
          safety, durability or reliability. The Utility shall not, by reason of
          such review or lack of review, be responsible for strength, details of
          design adequacy, or capacity of equipment built pursuant to such
          specifications, nor shall the Utility acceptance be deemed an
          endorsement of any such equipment.

     7.   No generating source shall be operated in parallel with the Utility's
          system until the interconnection facilities have been inspected by the
          Utility and the Utility has provided written approval to the Producer.

     8.   Only duly authorized employees of the Utility are allowed to connect
          Producer-installed interconnection facilities to, or disconnect the
          same from, the Utility's overhead or underground lines.

B.   INTERCONNECTION FACILITIES

     1.   GENERAL: Interconnection facilities are all means required, and
          apparatus installed, to interconnect the Producer's generation with
          the Utility's system. Where the Producer desires to sell power to the
          Utility, interconnection facilities are also all means required, and
          apparatus installed, to enable the Utility to receive power deliveries
          from the Producer. Interconnection facilities may include, but are not
          limited to:
          a.   connection, transformation, switching, metering, communications,
               control, protective and safety equipment; and
          b.   any necessary additions to and reinforcements of the Utility's
               system by the Utility.

     2.   METERING
          a.   A Producer desiring to sell power to the Utility shall provide,
               install, own and maintain all facilities necessary to accommodate
               metering equipment specified by the Utility. Such metering
               equipment may include meters telemetering (applicable where
               deliveries to the Utility exceed 10 MIW) and other recording and
               communications devices as may be required for the reporting of
               power delivery an to the Utility. Except as provided for in
               Section B.2.b following, the Utility shall provide, install, own
               and maintain all metering equipment as special facilities in
               accordance with Section F.
                                                                     (Continued)
--------------------------------------------------------------------------------

Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

                                     E-2(a)
<PAGE>

Pacific Gas and Electric Company            Revised Cal. P.U.C. Sheet No. 8617-E
   San Francisco. California    Cancelling Original Cal. P.U.C. Sheet No. 7694-E
--------------------------------------------------------------------------------
          RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION (Cont'd.)

B.   INTERCONNECTION FACILITIES

     2.   METERING

          b.   The Producer may at its option provide, install, own and maintain
               current and potential transformers rated above 600 volts and a
               non-revenue type graphic recorder where applicable. Such metering
               equipment, its installation and maintenance shall all be In
               conformance with the Utility's specifications.

          c.   The Utility's meters shall be equipped with detents to prevent
               reverse registration so that power deliveries to and from the
               Producer's equipment can be separately recorded.

     3.   CONTROL, PROTECTION AND SAFETY EQUIPMENT

          a.   GENERAL: The Utility has established functional requirements
               essential for safe and reliable parallel operation of the
               Producer's generation. These requirements provide for control,
               protective and safety equipment to:
               (1) sense and properly react to failure and malfunction on the
               Utility's system;
               (2) assist the Utility in maintaining its system integrity and
               reliability; and
               (3) protect the safety of the public and the Utility's personnel.

          b.   Listed below are the various devices and features generally
               required by the Utility as a prerequisite to parallel operation
               of the Producer's generation:

         CONTROL. PROTECTION AND SAFETY EQUIPMENT GENERAL REQUIREMENTS(1)
--------------------------------------------------------------------------------
<TABLE>
<CAPTION>
                                                                                      GENERATOR SIZE
                                                                                      --------------
                                                        10 kw or    11 kw to    41 kw to   101 kW to     401 kw to     Over
                    Device or Feature                     Less       40 kw       100 kw     400 kw       1,000 kw    1,000 kw
                    -----------------                     ----       -----       ------     ------       --------    --------
<S>                                                        <C>
Dedicated Transformer(2)                                    -           X          X           X            X            X
Interconnection Disconnect Device                           X           X          X           X            X            X
Generator Circuit Breaker                                   X           X          X           X            X            X
Over-voltage Protection                                     X           X          X           X            X            X
Under-voltage Protection                                    -           -          X           X            X            X
Under/Over-frequency Protection                             X           X          X           X            X            X
Ground Fault Protection                                     -           -          X           X            X            X
Over-current relay w/Voltage Restraint                      -           -                      -            X            X
Synchronizing(3)                                         Manual     Manual      Manual      Manual       Manual     Automatic
Power Factor or Voltage Regulation                                                 X           X            X            X
</TABLE>

          c.   DISCONNECT DEVICE: The producer shall provide, install, own and
               Maintain the interconnection disconnect device required by
               Section 8.3.b at a location readily accessible to the Utility.
               Such device shall normally be located near the Utility's meter or
               meters for sole operation by the Utility. The interconnection
               disconnect device and its precise location shall be specified by
               the Utility. At the Producer's option and request, the Utility
               will provide, Install, own and maintain the disconnect device on
               the Utility's system as special facilities in accordance with
               Section F.

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

1    Detailed requirements are specified in the Utility's current operating,
     metering and equipment protection publications, as revised from time to
     time by the Utility and available to the Producer upon request. For a
     particular generator application, the Utility will furnish its specific
     control, protective and safety requirements to the Producer after the exact
     location of the generator has been agreed upon and the interconnection
     voltage level has been established.

2    This is a transformer interconnected with no other Producers and serving no
     other Utility customers. Although the dedicated transformer is not a
     requirement for generators rated 10 kw or less, its installation is
     recommended by the Utility.

3    This Is a requirement for synchronous and other types of generators with
     stand-alone capability. For all such generators, the Utility will also
     require the installation of "reclose blocking" features on its system to
     block certain operations of the Utility's automatic line restoration
     equipment.
                                                                     (Continued)
--------------------------------------------------------------------------------

Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

                                    E-2 (b)
<PAGE>

Pacific Gas and Electric Company           Original Cal. P.U.C. Sheet No. 8618-E
   San Francisco. California    Cancelling ________ Cal. P.U.C. Sheet No. ______
--------------------------------------------------------------------------------
          RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION (Cont'd.)

B.   INTERCONNECTION FACILITIES (continued)

     4.   UTILITY SYSTEM ADDITIONS AND REINFORCEMENTS

          a.   Except as provided for in Section B.5. all additions to and
               reinforcements of the Utility's system necessary to interconnect
               with and receive power deliveries from the Producer's generation
               will be provided, installed, owned and maintained by the Utility
               as special facilities in accordance with Section F. Such
               additions and reinforcements may include the installation of a
               Utility distribution or transmission line extension or the
               increase of capacity in the Utility's existing distribution or
               transmission lines. The Utility shall determine whether any such
               additions or reinforcements shall include an increment of
               additional capacity for the Utility's use in furnishing service
               to its customers. If so, then the costs of providing, installing,
               owning and maintaining such additional capacity shall be Lorne by
               the Utility and/or its customers in accordance with the Utility's
               applicable tariffs on file with and authorized by the California
               Public Utilities Commission (Commission).

          b.   The Producer shall advance to the Utility its estimated costs of
               performing a preliminary or detailed engineering study as may be
               reasonably required to identify any Producer related Utility
               system additions and reinforcements. Where such. preliminary or
               detailed engineering study involves analysis of the Utility's
               transmission lines-(66 kv and higher), the Utility shall complete
               its study within twelve calendar months of receiving all
               necessary plans and specifications from the Producer.

     5.   PRODUCER-INSTALLED UTILITY-OWNED LINE EXTENSIONS: The Producer may at
          its option provide and install an extension of the Utility's
          distribution or transmission lines where required to complete the
          Producer's interconnection with the Utility. Such extension shall be
          installed by contractors approved by the Utility and in accordance
          with its design and specifications. The Producer shall pay the Utility
          its estimated costs of design, administration and inspection as may be
          reasonably required to assure such extension is installed in
          compliance with the Utility's requirements. Upon final inspection and
          acceptance by the Utility, the Producer shall transfer ownership of
          the line extension to the Utility where thereafter it shall be owned
          and maintained as special facilities in accordance with Section F.
          This provision does not preclude the Producer from installing, owning
          and maintaining a distribution or transmission line extension as part
          of its other Producer-owned interconnection facilities.

     6.   COSTS OF FUTURE UTILITY SYSTEM ALTERATIONS; The Producer shall be
          responsible for the costs of only those future Utility system
          alterations which are directly related to the Producer's. presence or
          necessary to maintain the Producer's interconnection in accordance
          with the Utility's applicable operating, metering and equipment
          publication in effect when the Producer and the Utility entered into a
          written form of power purchase agreement. Alterations made at the
          Producer's expense shall specifically exclude increases of existing
          line capacity necessary to accommodate the other Producers or Utility,
          customers. Such alterations may, however, include relocation or
          undergrounding of the Utility's distribution or transmission lines as
          may be ordered by a governmental authority having jurisdiction.

     7.   ALLOCATION OF THE UTILITY'S EXISTING LINE CAPACITY: For two or more
          Producers seeking to use an existing line, a first come, first served
          approach shall be used. The first Producer to request an
          interconnection shall have the right to use the existing line and
          shall incur no obligation for costs associated with future line
          upgrades needed to accommodate other Producers or customers. The
          Utility's power purchase agreement shall specify the date by which the
          Producer must begin construction. If that date passes and construction
          has not commenced, the Producer shall be given 30 days to correct the
          deficiency after receiving a reminder from the Utility that the
          construction start-up date has passed. If construction has not
          commenced after the 30-day corrective period, the Utility shall have
          the right to withdraw its commitment to the first Producer and offer
          the right to interconnect on the existing line to the next Producer in
          order. If two Producers establish the right of first-in-time
          simultaneously, the two Producers shall share the costs of any
          additional line upgrade necessary to facilitate their cumulative
          capacity requirements. Costs shall be shared based on the relative
          proportion of capacity each Producer will add to the line.

                                                                     (Continued)
--------------------------------------------------------------------------------
Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

<PAGE>

Pacific Gas and Electric Company            Revised Cal. P.U.C. Sheet No. 8619-E
   San Francisco. California    Cancelling Original Cal. P.U.C. Sheet No. 7695-E
--------------------------------------------------------------------------------
          RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION (Cont'd.)

C.   ELECTRIC SERVICE FROM THE UTILITY: If the Producer requires regular,
     supplemental, interruptible or standby service from the Utility, the
     Producer shall enter Into separate contractual arrangements with the
     Utility in accordance with the Utility's applicable electric tariffs on
     file with and authorized by the Commission.

D.   OPERATION

     1.   PREPARALLEL INSPECTION: In accordance with Section A.7, the Utility
          will inspect the Producer's interconnection facilities prior to
          providing it with written authorization to commence parallel
          operation. Such inspection shall determine whether or not the Producer
          has installed certain control, protective and safety equipment to the
          Utility's specifications, Where the Producer's generation has a rated
          output in excess of 100 kw, the Producer shall pay the Utility its
          estimated costs of performing the inspection.

     2.   JURISDICTION OF THE UTILITY'S SYSTEM DISPATCHER: The Producer's
          generation while operating in parallel with the Utility's system is at
          all times under the jurisdiction of the Utility's system dispatcher.
          The system dispatcher shall normally delegate such control to the
          Utility's designated switching center.

     3.   COMMUNICATIONS: The Producer shall maintain telephone service from the
          local telephone company to the location of the Producer's generation.
          In the event such location is remote or unattended, telephone service
          shall be provided to the nearest building normally occupied by the
          Producer's generator operator. The Utility and the Producer shall
          maintain operating communications through the Utility's designated
          switching center.

     4.   GENERATOR LOG: The Producer shall at all times keep and maintain a
          detailed generator operations log. Such log shall include, but not be
          limited to, information on unit availability, maintenance outages,
          circuit breaker trip operations requiring manual reset and unusual
          events. The Utility shall have the right to review the Producer's log.

     5.   REPORTING ABNORMAL CONDITIONS: The Utility shall advise the Producer
          of abnormal conditions which the Utility has reason to believe could
          affect the Utility's operating conditions or procedures. The Producer
          shall keep the Utility similarly informed.

     6.   POWER FACTOR: The Producer shall furnish reactive power as way be
          reasonably required by the Utility.

          a.   The Utility reserves the right to specify that generators with
               power factor control capability, Including synchronous
               generators, be capable of operating continuously at any power
               factor between 95 percent leading (absorbing vars) and 90 percent
               tagging (producing vars) at any voltage level within + or - 5.0
               percent of rated voltage. For other types of generators with no
               inherent power factor control capability, the Utility reserves
               the right to specify the installation of capacitors by the
               Producer to correct generator output to near 95 percent leading
               power factor. The Utility may also require the installation of
               switched capacitors on its system to produce reactive support
               equivalent to that provided by operating a synchronous generator
               of the some size between 95 percent leading and 90 percent
               lagging power factor.
          b.   Where either the Producer or the Utility determines that it Is
               not practical for the Producer to furnish the Utility's required
               level of reactive power or when the Utility specifies switched
               capacitors in its system pursuant to Section D.6.a, the Utility
               will provide, install, own and maintain the necessary devices on
               its system in accordance with Section F.

E.   INTERFERENCE WITH SERVICE AND COMMUNICATION FACILITIES

     1.   CEMERAL: The Utility reserves the right to refuse to connect to any
          new equipment or to remain connected to any existing equipment of a
          size or character that may be detrimental to the Utility's operations
          or service to its customers.

                                                                     (Continued)
--------------------------------------------------------------------------------
Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

<PAGE>

Pacific Gas and Electric Company            Revised Cal. P.U.C. Sheet No. 8620-E
   San Francisco. California    Cancelling Original Cal. P.U.C. Sheet No. 7696-E
--------------------------------------------------------------------------------
          RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION (Cont'd.)

E.   INTERFERENCE WITH SERVICE AND COMMUNICATION FACILITIES (continued)

     2.   The Producer shall not operate equipment that superimposes upon the
          Utility's system a voltage or current which causes interference with
          the Utility's operations, service to the Utility's customers or
          interference to communication facilities. If the Producer causes
          service interference to others, the Producer must diligently pursue
          and take corrective action at the Producer's expense after being given
          notice and reasonable time to do so by the Utility. If the Producer
          does not take timely corrective action, or continues to operate the
          equipment causing the interference without restriction or limit, the
          Utility may, without liability, disconnect the Producer's equipment
          from the Utility's system until a suitable permanent solution provided
          by the Producer is operational at the Producer's expense.

F.   SPECIAL FACILITIES

     1.   Where the Producer requests the Utility to furnish interconnection
          facilities or where it is necessary to make additions to or
          reinforcements of the Utility's system and the Utility agrees to do
          so, such facilities shall be deemed to be special facilities and the
          costs thereof' shall be borne by the Producer, including such
          continuing ownership costs as may be applicable.

     2.   Special facilities are (a) those facilities installed. at the
          Producer's request which the Utility does not normally furnish under
          its tariff schedules, or (b) a prorate portion of existing facilities
          requested by the Producer, allocated for the sole use of such
          Producer, which would not normally be allocated for such sole use.
          Unless otherwise provided by the Utility's filed tariff schedules,
          special facilities will be installed, owned and maintained or
          allocated by the Utility as an accommodation to the Producer only if
          acceptable for operation by the Utility and the reliability of service
          to the Utility's customers is not impaired.

     3.   Special facilities will be furnished under the terms and conditions of
          the Utility's "Agreement for installation or Allocation of Special
          Facilities for Parallel Operation of Nonutility-owned Generation
          and/or Electrical Standby Service" (Form 79-280, effective June 1984)
          and its Appendix A, "Detail of Special Facilities Charges" (Form
          79-702, effective June 1984). Prior to the Producer signing such an
          agreement, the Utility shall provide the Producer with a breakdown of
          special facilities costs in a form having detail sufficient for the
          information to be reasonably understood by the Producer. The special
          facilities agreement will include, but is not limited to, a binding
          quotation of charges to the Producer and the following general terms
          and conditions:

          a.   Where facilities are installed by the Utility for the Producer's
               use as special facilities, the Producer shall advance to the
               Utility its estimated installed cost of the special facilities.
               The amount advanced is subject to the monthly ownership charge
               applicable to customer-financed special facilities as set forth
               in Section I of the Utility's Rule No. 2.

          b.   At the Producer's option, and where such Producer's generation is
               a qualifying facility and the Producer has established credit
               worthiness to the Utility's satisfaction, the Utility shall
               finance those special facilities it deems to be removable and
               reusable equipment. Such equipment shall include, but not be
               limited to, transformation, disconnection and metering equipment.

          c.   Existing facilities allocated for the Producer's use as special
               facilities and removable and reusable equipment financed by the
               Utility in accordance with Section F.3.b are subject to the
               monthly ownership charge applicable to Utility-financed special
               facilities as set forth in Section 1 of Rule 2.

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

4    A qualifying facility is one which meets the requirements established by
     the Federal Energy Regulatory Commission's rules (18 Code of Federal
     Regulations 292) implementing the Public Utility Regulatory Policies Act of
     1978 (16 U.S.C.A. 796, et seq.).
--------------------------------------------------------------------------------
Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

<PAGE>
Pacific Gas and Electric Company           Original Cal. P.U.C. Sheet No. 8621-E
   San Francisco. California    Cancelling ________ Cal. P.U.C. Sheet No. ______
--------------------------------------------------------------------------------
          RULE NO. 21 -- NONUTILITY-OWNED PARALLEL GENERATION (Cont'd.)

F.   SPECIAL FACILITIES (continued)

          d.   Where the Producer elects to install and deed to the Utility an
               extension of the Utility's distribution or transmission lines for
               use as special facilities in accordance with Section 8.5, the
               Utility's estimate of the installed cost of such extension shall
               be subject to the monthly ownership charge applicable to
               customer-financed special facilities as set forth in Section I of
               the Rule No. 2.

     4.   Where payment or collection of continuing monthly ownership charges is
          not practicable, the Producer shall be required to make an equivalent
          one-time payment in lieu of such monthly charges.

     5.   Costs of special facilities borne by the Producer may be subject to
          downward adjustment when such special facilities are used to furnish
          permanent service to a customer of the Utility. This adjustment will
          be based upon the extension allowance or other such customer allowance
          which the Utility would have utilized under its then applicable
          tariffs if the special facilities did not otherwise exist. In no event
          shall such adjustment exceed the original installed cost of that
          portion of the special facilities used to serve a now customer. An
          adjustment, where applicable, will consist of a refund applied to the
          Producer's initial payment. for special facilities and/or a
          corresponding reduction of the ownership charge.

G.   EXCEPTIONAL CASES: Where the application of this rule appears impractical
     or unjust, the Producer may refer the matter to the Commission for special
     ruling or for the approval of special conditions.

H.   INCORPORATION INTO POWER PURCHASE AGREEMENTS: Pursuant to Decision No.
     83-10-093, if in accordance with Section A.4 the Producer enters into a
     written form of power purchase agreement with Utility, a copy of the Rule
     No. 21 in effect on the date of execution will be appended to, and
     Incorporated by reference into such power purchase agreement. The Rule
     appended to such power purchase agreement shall then be applicable for the
     term of the Producer's power purchase agreement with the Utility.
     Subsequent revisions to this rule shall not be Incorporated into the rule
     appended to such power purchase agreement.

--------------------------------------------------------------------------------
Advice Letter No.  1025-E                                Date Filed May 21, 1984
Decision No.      83-10-093                              Effective June 20, 1984
                                                         Resolution No.

                                    Issued By
                                 W. M. Gallavan
                                 Vice-President
                          Rates and Economic Analysis

                                      E-2(f)
<PAGE>

E-2  POINT OF DELIVERY LOCATION SKETCH

     The Seller requests, and PGandE consents, that the location sketch not be
made at the time of executing the Agreement, because the Seller, recognizing
that the information is not yet available to make a definitive determination of
the sketch to be inserted here, shall request PGandE to perform an
interconnection study to be done in its accustomed manner of making such studies
to determine the sketch to be inserted.

                                      E-3
<PAGE>

E-3  INTERCONNECTION FACILITIES FOR WHICH SELLER IS RESPONSIBLE

     The Seller requests, and PGandE consents, that this listing of facilities
not be filled in at the time of executing the Agreement, because the Seller,
recognizing that the information is not yet available to make a definitive
determination of the listing of facilities to be inserted here, shall request
PGandE to perform an interconnection study to be done in its accustomed manner
of making such studies to determine the listing of facilities to be inserted.

                                      E-4

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