Document:

AMENDMENT TO THE

                               LONG TERM AGREEMENT

                                       FOR

                        PURCHASE AND SALE OF ELECTRICITY

                      BETWEEN SIERRA PACIFIC POWER COMPANY

                                       AND

                        NEVADA GEOTHERMAL POWER PARTNERS

                      AMENDMENT TO THE LONG TERM AGREEMENT

                      FOR PURCHASE AND SALE OF ELECTRICITY

                      FOR NEVADA GEOTHERMAL POWER PARTNERS

                                TABLE OF CONTENTS

SECTION   NAME                                                              PAGE
-------   ----                                                              ----
   1.     Recitals.......................................................      1
   2.     Amendment Term.................................................      2
   3.     Brady Contract Termination.....................................      2
   4.     Rate...........................................................      2
   5.     Guarantees.....................................................      3
   6.     Sale of Capacity and Energy....................................      4
   7.     Continuity of Deliveries and Economic Dispatch.................      5
   8.     Project Schedule...............................................      6
   9.     Insurance......................................................      6
   10.    Exhibits.......................................................      7
   11.    Status of Amendment............................................      7
   12.    Multiple Originals.............................................      8

Attachment #1 - Amendment No. 1 to Exhibit B
Attachment #2 - Amendment No. 1 to Exhibit D
Attachment #3 - Amendment No. 1 to Exhibit E
Attachment #4 - Amendment No. 1 to Exhibit O

                      AMENDMENT TO THE LONG TERM AGREEMENT
                      FOR PURCHASE AND SALE OF ELECTRICITY
                      FOR NEVADA GEOTHERMAL POWER PARTNERS

     This Amendment is entered into as of the date of execution by and among
Brady Power Partners, a Nevada general partnership ("Seller") the general
partners of which are ESI BH Limited Partnership, a Delaware limited
partnership, with ESI Brady, Inc., a Florida corporation, a wholly-owned
subsidiary of ESI Energy, Inc., a Florida corporation, as its sole general
partner, and Nevada Geothermal Power Partners Limited Partnership, a Nevada
limited partnership ("NGPP"), with Hot Springs Power Company, a Nevada
corporation, as its managing general partner and Sierra Pacific Power Company, a
Nevada corporation ("Sierra"). Seller and Sierra are sometimes referred to
collectively as "Parties".

1. Recitals. This Amendment is based upon the following facts:

     a. Sierra and Brady Hot Springs Geothermal Associates ("Brady") entered
into a Long-Term Agreement for the Purchase and Sale of Electricity dated
October 10, 1986 ("Brady Contract").

     b. A Settlement Agreement between Sierra and Brady was entered into on
October 19, 1990 as a result of an action filed by Brady on August 11, 1988 in
the Second Judicial District Court of the State of Nevada, in and for the County
of Washoe, captioned, "Brady Hot Springs Geothermal Associates v. Sierra Pacific
Power Company," Case No. CV88-4652.

     c. Sierra and NGPP entered into a separate Long-Term Agreement for the
Purchase and Sale of Electricity dated October 5, 1990 ("Agreement").

                                     Page 1                               7/3/91

     d. NGPP has requested an extension of time to perform milestones and meet
project schedule requirements to allow for a reasonable schedule for development
of the Project.

     e. NGPP has assigned its rights, duties, and obligations under the
Agreement to Seller and Sierra has consented to that assignment.

     f. Seller and Sierra have agreed to combine the Agreement and the Brady
Contract into one single contract by terminating the Brady Contract and amending
the Agreement to reflect a combined plant of 19.9 MW of capacity.

     In consideration of the promises and covenants contained herein, the
Parties agree as follows:

2. Amendment Term. This Amendment shall be effective at 2400 hours on the
effective date of Sierra's Consent to Assignment of the Brady Contract from
Brady Hot Springs Geothermal Associates to Seller ("Effective Date") and shall
continue until the Agreement is terminated.

3. Brady Contract Termination. Upon the Effective Date of this Amendment, the
Brady Contract shall be terminated in its entirety.

4. Rate. Subsections 8.(c) and 8 (d) of the Agreement are amended to read as
follows:

          "(c) If the Commercial Operation Date of the Project is on or before
     2400 hours on August 20, 1992, then Sierra shall pay Seller, during the
     period commencing on the Commercial Operation Date and continuing for the
     Term, for all Adjusted Net Metered Output purchased from Seller's Project
     pursuant to the applicable provisions set forth in Exhibit D.

          (d) If the Commercial Operation Date of the Project is after 2400
     hours on August 20, 1992, but on or before 2400 hours on

                                     Page 2                               7/3/91

     November 20, 1992, then Sierra shall pay Seller, during the period
     commencing on the Commercial Operation Date and continuing for the Term,
     for all Adjusted Net Metered Output purchased from Seller's Project
     pursuant to the applicable provisions set forth in Exhibit D."

5. Guarantees. Section 11. Guarantees of the Agreement is hereby replaced and
shall read as follows:

          "11. Guarantees. (a) Upon financial closing of the Project, but in no
     event later than July 31, 1991, Seller shall provide to Sierra $231,000 as
     an additional amount of earnest money deposit. The deposit may be in the
     form of cash, an irrevocable letter of credit or any other form acceptable
     to Sierra. Such deposit, if other than cash, shall list Sierra as
     beneficiary and provide Sierra with clear first rights to the deposit in
     the event of a default as noted in subsection (b) below. Seller has
     previously advanced to Sierra an earnest money deposit of $67,500. The
     total earnest money amount of $298,500 is based upon a fee of $15.00 per KW
     and a capacity of 19,900 KW.

          (b) In the event Seller does not complete a milestone in accordance
     with Section 9 of this Agreement, withdraws the Project, cancels the
     Project for any reason including force majeure, or does not achieve a
     Commercial Operation Date pursuant to Section 7 on or before 2400 hours on
     August 20, 1992, Seller shall forfeit its $298,500 deposit to Sierra.

          (c) Sierra will refund the deposit to Seller or apply it against any
     outstanding balance if Seller establishes a Commercial Operation Date for
     the Project, pursuant to Section 7 of this Agreement, on or before 2400
     hours on August 20, 1992."

                                     Page 3                               7/3/91

6. Sale of Capacity and Energy. Section 6.(a)(2) of the Agreement is amended to
read as follows:

          "(2) Firm Energy which is expected to total approximately 164,241,400
     kilowatt hours in any Contract Year subject to the restrictions specified
     in Section 15 of this Agreement."

Section 6.(b) of the Agreement is amended to read as follows:

          "(b) At the end of the third Contract Year, and the end of each
     Contract Year thereafter, Sierra shall perform the following calculations:
     1) calculate the three year average of the Peak Period Capacity for the
     three immediately preceding years by adding the billing period Peak Period
     Capacity for those thirty-six (36) months and dividing by thirty-six (36).
     2) If such average is below 95% and greater than or equal to 85% of the
     Peak Period Capacity value in Exhibit B, then the capacity rate for the
     next year shall be reduced 1% for each percent or portion thereof that the
     average is below 100%; 3) If the average is less than 85% of the Peak
     Period Capacity value in Exhibit B, then the Seller shall pay Sierra the
     sum of $1,500,000 as and for liquidated damages. This shall be a lump sum
     payment in 1990 dollars and shall be escalated at GNPD beginning the year
     1991 up to the year of the payment. This amount will be billed as soon as
     reasonably practicable after the determination of the three year average
     and shall be due within thirty (30) days of such billing.

          If the three year rolling average is less than 85% of the Average Peak
     Period Capacity Value then specified in Exhibit B, then each of the Exhibit
     B Peak Period Capacity values shall be replaced by the average Peak Period
     Capacity value for that billing period in the three year period described
     above. Said average Peak Period Capacity value

                                     Page 4                               7/3/91

     shall be calculated by adding the Peak Period Capacity value for that
     billing period in each of the previous three years and dividing by 3.
     Sierra shall prepare a revised Exhibit B to incorporate such revised Peak
     Period Capacity values and such revised values shall be used thereafter,
     effective the first month of the new Contract Year. The capacity rate will
     revert back to the amount specified in Exhibit D effective with the revised
     Exhibit B. At the end of the next three contract years, and the end of each
     Contract Year thereafter, Sierra shall repeat the calculations 1, 2, and 3
     above."

7. Continuity of Deliveries and Economic Dispatch. Section 15.(b) of the
Agreement is amended to read as follows:

          "(b) Sierra shall have the right to economically dispatch the Project
     for a maximum of 6,000,000 kilowatt hours of Adjusted Net Metered Output
     each Contract Year. Such economic dispatch capability shall be exercised by
     verbal notice to Seller by Sierra by 1000 hours on the day preceding the
     day on which the Project will be economically dispatched. Such notice shall
     include the hours and the reduced energy price for such hours. Seller shall
     have the option of accepting the reduced energy payment as specified by
     Sierra at the time of such notice for continued deliveries of capacity and
     energy, or discontinuing delivery of capacity and energy for the period
     described in Sierra's notice. Seller shall notify Sierra verbally by 1100
     hours of the option Seller has selected.

          For any month in which Sierra exercises its economic dispatch rights
     for energy under this subsection, Sierra shall provide Seller an accounting
     of the reduced energy price contained in the verbal notice

                                     Page 5                               7/3/91

     by Sierra to Seller. Such accounting shall be included as part of the
     following month's payment to Seller as provided in Section 13."

8. Project Schedule.

     (A) Section 9.(b) of the Agreement is amended to read as follows:

          "(b) Seller shall provide Sierra with the specific amounts of: (1)
     steam in pounds per hour, (2) pressure in pounds per square inch and (3)
     temperature in degrees Fahrenheit, (all measured or recorded at the turbine
     inlet valve) which are necessary to operate the Project at the average of
     the Peak Period Capacity value specified in Exhibit B. Data shall be
     provided to Sierra by 2400 hours on September 16, 1991. Subject to Sierra's
     review and acceptance, Seller may change this data no later than the date
     of completion of Item 3 in Exhibit O. This information will be used as a
     baseline and monitoring tool for items 3 and 7 in Exhibit O."

9. Insurance. Section 20 (b) of the Agreement is amended to read as follows:

          "(b) Prior to connection of the Project to Sierra's system, Seller
shall secure and continuously carry for the Term hereof, with an insurance
company or companies acceptable to Sierra, insurance policies for bodily injury
and property damage liability. Such acceptance shall not be unreasonably
withheld. Such insurance shall include: provisions or endorsements naming Sierra
as additional insured as its interest may appear; provisions that such insurance
is primary insurance with respect to the interest of Sierra and that any
insurance maintained by Sierra is excess and not contributory insurance with the
insurance required hereunder; cross-liability or severability of insurance
interest clause; and provisions that such policies shall not be cancelled or
their limits of liability

                                     Page 6                               7/3/91

reduced without thirty (30) days prior written notice to Sierra. Initial limits
of liability for all requirements under this Section shall be not less than
$2,000,000 for each occurrence."

10. Exhibits. Exhibits B, D, E and O of the Agreement are replaced by the
Exhibits B, D, E, and O attached hereto.

11. Status of Amendment. It is expressly understood and agreed by the Parties
hereto that this Amendment is supplemental to the Agreement. It is further
understood and agreed that all the terms, conditions, and provisions of the
Agreement, unless specifically modified herein are to apply to this Amendment
and are made part of the Amendment as though they were expressly rewritten,
incorporated and included herein.

                                     Page 7                               7/3/91

12. Multiple Originals. Three (3) copies of this Agreement have been executed by
the Parties. Each executed copy shall be deemed an original.

     IN WITNESS WHEREOF, the Parties hereto have executed this Amendment on this
12 day of July, 1991. Acknowledged and Agreed To By:

BRADY POWER PARTNERS

BY: NEVADA GEOTHERMAL POWER PARTNERS,
    LIMITED PARTNERSHIP, A GENERAL PARTNER

BY: HOT SPRINGS POWER COMPANY, ITS MANAGING
    GENERAL PARTNER

BY: /s/ RANDY S. GOLDENHERSH
    ---------------------------
    RANDY S. GOLDENHERSH,
    PRESIDENT

DATE: 7/8/91

BY: ESI BH LIMITED PARTNERSHIP, A GENERAL
    PARTNER

BY: ESI BRADY, INC., ITS GENERAL PARTNER

BY: /s/ LARRY K. CARPENTER
    ---------------------------
    LARRY K. CARPENTER
    PRESIDENT

DATE:
      -------------------------

SIERRA:

SIERRA PACIFIC POWER COMPANY

BY: /s/ GERALD W. CANNING
    ---------------------------
    GERALD W. CANNING
    VICE PRESIDENT,
    ELECTRIC RESOURCES

DATE: 7/12/91

---------
  APPVD.
---------
____
---------
____
---------

                                     Page 8                               7/3/91

                                                      Exhibit A
                                                      To Long Term Agreement
                                                      For The Purchase and Sale
                                                      of Electricity Between
                                                      Sierra Pacific Power
                                                      Company and Brady Power
                                                      Partners Effective Upon
                                                      Execution

                              PROJECT UNIT LISTING

TURBINE NAMEPLATE:

                       Two High Pressure Units                                 One Low Pressure Unit
                       -----------------------                                 ---------------------

Manufacturer:          General Electric                                        General Electric
Model:                 CL55                                                    CL55
Type:                  Double Flow                                             Double Flow
Rating:                8058 KW @ 51.52 psia inlet,                             7839 KW @ 26.55 psia inlet,
                       2.5" HGA exhaust                                        2.5" HGA exhaust

GENERATOR NAMEPLATE: (Same for all turbines)
Manufacturer:          Ideal Electric
Model:                 SAB
Type:                  Synchronous, Horizontal, TEWAC
Rating:                8889 KVA, 8000 KW, 0.9 pf
Voltage:               12.5 KV, 3 phase, Y-connected, 60 Hz
Speed:                 1800 rpm
Temperature Rise:      80(DEG.)C by resistance above a 40(DEG.)C ambient
Insulation:            Class F
Additional Features:   Damper Windings
                       Brushless Exciter
                       Permanent Magnet Alternator
                       Static Voltage Regulator

The power plant will consist of two high pressure units and one low pressure
unit, each with nameplate data as presented above. They will be supplied by
Geothermal Power Company of Elmira, New York, as skid-mounted units complete
with speed reduction gear, lube-oil system, steam inlet control valves,
hydraulic oil system, and switchgear.

BRADY POWER PARTNERS

By: NEVADA GEOTHERMAL POWER PARTNERS, LIMITED PARTNERSHIP,
    A GENERAL PARTNER

    By: Hot Springs Power Company, a general partner

    By: /s/ Randy Goldenhersh
        ------------------------

    By: Randy Goldenhersh, President

    Date: 11/20/91

By: ESI BH, LIMITED PARTNERSHIP, A GENERAL PARTNER

    By: ESI BH Limited Partnership, a general partner

    By: /s/ Larry K. Carpenter
        ------------------------

    By: Larry K. Carpenter, President

    Date: 12-9-91

SIERRA PACIFIC POWER COMPANY

By: /s/ Gerald W. Canning                                              ---------
    ----------------------------                                         APPVD.
    Gerald W. Canning, Vice President, Electric Operations             ---------
                                                                       ___   ___
    Date: 12/20/92                                                     ---------

                                                                       ---------

                                                                   ATTACHMENT #1
                                                                       EXHIBIT B
                                                                 AMENDMENT NO. I
                                                                     Page 1 of 1

                                 CAPACITY TABLE
                    NEVADA GEOTHERMAL POWER PARTNER'S PROJECT

BILLING PERIOD                                    PEAK PERIOD CAPACITY VALUE: KW
--------------                                    ------------------------------
JANUARY.........................................               19,900
FEBRUARY........................................               19,600
MARCH...........................................               19,100
APRIL...........................................               18,700
MAY.............................................               18,300
JUNE............................................               17,800
JULY............................................               17,700
AUGUST..........................................               17,700
SEPTEMBER.......................................               18,300
OCTOBER.........................................               19,000
NOVEMBER........................................               19,300
DECEMBER........................................               19,700
                                                               ------
AVERAGE OF THE PEAK PERIOD CAPACITY VALUES, KW..               18,700

                                                                       EXHIBIT C
                                                                       1 of 4

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              15th Revised   P.S.C.N. Sheet No. 2
Tariff No. Electric No. 2      Cancelling 14th Revised   P.S.C.N. Sheet No. 2

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

                                SCHEDULE NO. CSPP

                                SHORT-TERM RATES
                     COGENERATION AND SMALL POWER PRODUCTION

APPLICABILITY

          This schedule is applicable only to purchases from Qualifying
Facilities as defined in Utility's Nevada Electric Tariff No. 1 Rule No. 15
under a Short-Term Purchase Agreement with Utility and where no other schedules
are specifically applicable.

RATES

          Utility will pay the sum of the following rates for the energy and
capacity provided as determined by meter readings:

     (1)  ENERGY RATE

     a.   Time-differentiated:

                                                                   1992
                                           -----------------------------------------------------
                                           1st Quarter   2nd Quarter   3rd Quarter   4th Quarter
                                           01/01-03/31   04/01-06/30   07/01-09/30   10/01-12/31
                                           -----------   -----------   -----------   -----------

     Winter
          All On-Peak kWh, per kWh           $0.02247      $0.01760        N/A         $0.01969
          Plus all Mid-Peak kWh, per kWh     $0.02190      $0.01763        N/A         $0.01990
          Plus all Off-Peak kWh, per kWh     $0.01882      $0.01772        N/A         $0.01792

     Summer
          All On-Peak kWh, per kWh             N/A         $0.01717      $0.01847        N/A
          Plus all Off-Peak kWh, per kWh       N/A         $0.01726      $0.01790        N/A

     b.   Non-time differentiated: (See Special Condition 3)

          All kWh, per kWh                   $0.02087      $0.01751      $0.01818      $0.01911

                                   (Continued)

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

Issued: 01/01/92
                                      Issued By:
Effective: 01/01/92               William L. Keepers
                                      President
Advice No.: 308-E

                                   Appendix E
                                   Page 1 of 4

                                                                       EXHIBIT C
                                                                       2 of 4

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              15th Revised   P.S.C.N. Sheet No. 3
Tariff No. Electric No. 2      Cancelling 14th Revised   P.S.C.N. Sheet No. 3

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

                                SCHEDULE NO. CSPP

                                SHORT-TERM RATES
                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

RATES (Continued)

(2)  CAPACITY RATE

a.   Time-differentiated:
                                         1992
                                       -------
Winter
     All On-Peak kWh, per kWh          $.00959
     Plus all Mid-Peak kWh, per kWh    $.00859
     Plus all Off-Peak kWh, per kWh    $.00506

Summer
     All On-Peak kWh, per kWh          $.00796
     Plus all Off-Peak, kWh, per kWh   $.00516

b.   Non-time differentiated: (See Special Condition 3)

     All kWh, per kWh                  $.00717

SPECIAL CONDITIONS

1. The payment period for Utility purchases hereunder shall be the time interval
between two consecutive meter readings that are taken for billing purposes.

2. The Utility and the Qualifying Facility shall have executed a Short-Term
Purchase Agreement for the purchase and sale of capacity and energy.

3. Qualifying Facilities having rated (nameplate) capacities of 100 kW or less
shall have the option to choose either flat or time-differentiated rates.
Qualifying Facilities having rated (nameplate) capacities in excess of 100 kW
will receive payments based on the time-differentiated rates only.

                                   (Continued)

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

Issued: 01/01/92
                                      Issued By:
Effective: 01/01/92               William L. Keepers
                                      President
Advice No.: 308-E

                                   Appendix E
                                   Page 2 of 4

                                                                       EXHIBIT C
                                                                       3 of 4

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              15th Revised   P.S.C.N. Sheet No. 3
Tariff No. Electric No. 2      Cancelling 14th Revised   P.S.C.N. Sheet No. 3

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

                                SCHEDULE NO. CSPP

                                SHORT-TERM RATES
                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

RATES (Continued)

(2)  CAPACITY RATE

a.   Time-differentiated:
                                         1992
                                       -------
Winter
     All On-Peak kWh, per kWh          $.00959
     Plus all Mid-Peak kWh, per kWh    $.00859
     Plus all Off-Peak kWh, per kWh    $.00506

Summer
     All On-Peak kWh, per kWh          $.00796
     Plus all Off-Peak, kWh, per kWh   $.00516

b.   Non-time differentiated: (See Special Condition 3)

     All kWh per kWh                   $.00717

SPECIAL CONDITIONS

1. The payment period for Utility purchases hereunder shall be the time interval
between two consecutive meter readings that are taken for billing purposes.

2. The Utility and the Qualifying Facility shall have executed a Short-Term
Purchase Agreement for the purchase and sale of capacity and energy.

3. Qualifying Facilities having rated (nameplate) capacities of 100 kW or less
shall have the option to choose either flat or time-differentiated rates.
Qualifying Facilities having rated (nameplate) capacities in excess of 100 kW
will receive payments based on the time-differentiated rates only.

                                   (Continued)

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

Issued: 01/01/92
                                      Issued By:
Effective: 01/01/92               William L. Keepers
                                      President
Advice No.: 308-E

                                   Appendix E
                                   Page 3 of 4

                                                                       EXHIBIT C
                                                                       4 of 4

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              Original     P.S.C.N. Sheet No. 4
Tariff No. Electric No. 2      Cancelling              P.S.C.N. Sheet No.
                                          ----------                      --

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

                                SCHEDULE NO. CSPP

                                SHORT-TERM RATES
                     COGENERATION AND SMALL POWER PRODUCTION
                                  (Continued)

SPECIAL CONDITIONS, (Continued)

     4. Daily time periods will be based on Pacific time and are defined as
follows:

Winter Period     On-Peak   5:01 p.m. to 10:00 p.m. daily
                 Mid-Peak   7:00 a.m. to  5:00 p.m. daily
                 Off-Peak   All other hours

Summer Period     On-Peak   10:01 a.m. to 10:00 p.m. daily
                 Off-Peak   All other hours

     The winter period will consist of eight months from October through May.
The summer period will consist of four months from June through September.

     5. Qualifying Facilities providing energy to Utility hereunder shall be
entitled to receive electric service from Utility on the filed rates
schedule(s) contained in Utility's Nevada Electric Tariff No. 1 applicable to
the type and location of the Qualifying Facility.

     6. All purchases made under this schedule are subject to the provision of
Rule No. 15 as contained in Utility's Nevada Electric Tariff No. 1.

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

Issued:     6/23/86

                                   Issued By:
Effective:  6/23/86             Austin W. Stedham
                                    President

Advice No.: 249-E
            (Revised)

                                   Appendix E
                                   Page 4 of 4

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

                                                                   Attachment #2
                                                                       Exhibit D
                                                                 Amendment No. 1
                                                                Payment Schedule
                                                                     Page 1 of 4

1.   This payment schedule is applicable only to purchases of firm capacity and
     firm energy from the Nevada Geothermal Power Partner's Project described in
     this Agreement.

2.a. If Seller's Project establishes a Commercial Operation Date which meets the
     criteria specified in Section 7 of this Agreement and thereby qualifies for
     payments pursuant to this Exhibit, Sierra will pay for the total Firm
     Energy and Firm Capacity delivered as determined by the Adjusted Net
     Metered Output:

2.b. Subject to the provisions in Section 15(b) of the Agreement, the energy
     payment shall be the sum of the products of the appropriate energy rate and
     the corresponding period kWh Adjusted Net Metered Output.

     Energy payment = [E] Periods (kWh delivered x Energy Rate of Section
                                 2.b.(i) of this Exhibit x 2/3)

                    + [E] Periods (kWh delivered x Energy Rate of Section
                                 2.b.(ii) of this Exhibit x 1/3)

     (i) PERIOD       1991$ PER KILOWATT-HOUR BASE ENERGY RATE

                                                        Commercial Operation
                                 Commercial Operation        Date between
                                   Date on or before     August 20, 1992 and
                                    August 20, 1992       November 20, 1992
                                 --------------------   --------------------

     Winter
     All on-peak kWh, per kWh           $.02662                .02560
     All mid-peak kWh, per kWh          $.02583                .02484
     All off-peak kWh, per kWh          $.02334                .02244

     Summer
     All on-peak kWh, per kWh           $.02608                .02508
     All off-peak kWh, per kWh          $.02376                .02285

     These rates shall be subject to adjustment as noted in Section 6.a of this
     Exhibit.

                                                                   Attachment #2
                                                                       Exhibit D
                                                                 Amendment No. 1
                                                                Payment Schedule
                                                                     Page 2 of 4

     (ii) PERIOD     1991$ PER KILOWATT-HOUR BASE ENERGY RATE

                                                        Commercial Operation
                                 Commercial Operation        Date between
                                   Date on or before     August 20, 1992 and
                                    August 20, 1992       November 20, 1992
                                 --------------------   --------------------
     Winter
     All on-peak kWh, per kWh           $.03845                .03545
     All mid-peak kWh, per kWh          $.03740                .03440
     All off-peak kWh, per kWh          $.03408                .03108

     Summer
     All on-peak kWh, per kWh           $.03773                .03473
     All off-peak kWh, per kWh          $.03464                .03164

     These rates shall be subject to adjustment as noted in Section 6.b of this
     Exhibit.

If Seller has accepted a reduced rate for the sale of energy in accordance with
Section 15(b) of the Agreement, then such reduced rate specified in the verbal
notice shall be utilized in the calculation of payment for the Adjusted Net
Metered output delivered for the time period specified in the verbal notice.

2.c. The capacity payment shall be as noted below and shall be subject to
     adjustment as noted in Section 2 of this Exhibit.

     Capacity Payment = Capacity Rate of Section 2.c. (i) of this Exhibit x
                        Capacity Level x 2/3

                   +    Capacity Rate of Section 2.c. (ii) of this Exhibit x
                        Capacity Level x 1/3

     (i)    Capacity Rate            Effective Date
           ---------------   ----------------------------
           $20.25/kW Month   Commercial Operation Date

           $ 8.88/kW Month   Twentieth (20th) Anniversary
                             of Commercial Operation Date

     (ii)   Capacity Rate            Effective Date
           ---------------   ----------------------------
           $14.62/kW Month   Commercial Operation Date

                                                                   Attachment #2
                                                                       Exhibit D
                                                                 Amendment No. 1
                                                                Payment Schedule
                                                                     Page 3 of 4

               $6.41/kW Month                       Twentieth (20th) Anniversary
                                                    of Commercial Operation Date

Capacity Level = the lesser of:

     (a) The kWh generated during the Peak Period divided by the Peak Period or,

     (b) The monthly on-peak capacity value noted in Exhibit B corresponding to
     the billing period.

3.   The Peak Period will be reduced by the cumulative monthly total of Peak
     Period hours associated with Sierra's requirement to curtail Adjusted Net
     Metered Output pursuant to Sections 15 (a) and 15 (b) of the Agreement to
     the extent such monthly curtailment exceeds 4 hours. Only the hours of
     curtailment that exceed 4 hours shall be deducted on a monthly or
     cumulative basis. It shall be Seller's responsibility to maintain a log of
     the monthly and cumulative total of curtailment hours curtailed pursuant to
     subsection 15 (a) of the Agreement and notify Sierra monthly of such
     amounts.

4.   The billing period for Sierra purchases hereunder shall be the time
     interval between two consecutive meter readings that are taken for billing
     purposes.

5.   Daily time periods will be based on Pacific time and are defined as
     follows:

     Winter Period
     On-Peak    5:01 p.m. to 10:00 p.m. daily
     Mid-Peak   7:00 a.m. to 5:00 p.m. daily
     Off-Peak   All other hours

     Summer Period
     On-Peak    10:01 a.m. to 10:00 p.m. daily
     Off-Peak   All other hours

     The winter period will consist of eight (8) months from October through
     May. The summer period will consist of four (4) months from June through
     September.

     This table is excerpted from Electric Tariffs No. 2, PSCN Sheet No. 4,
     Schedule No. CSPP, and is subject to change in accord with the on-

                                                                   Attachment #2
                                                                       Exhibit D
                                                                 Amendment No. 1
                                                                Payment Schedule
                                                                     Page 4 of 4

     peak, mid-peak, and off-peak periods as described in SPPC's own rate
     schedules for the sale of electricity, as revised from time to time.

6.a. The energy rate contained in Section 2.b (i) of this Exhibit shall be
     adjusted on the first anniversary and each subsequent anniversary of the
     Commercial Operation Date of the Project. The adjustment shall be
     calculated as follows:

     R(n) = (1.04) R(n-1)

     R = the indexed rate
     n = the calendar year in which the adjustment takes place

     The capacity rates in Section 2.c. (i) of this Exhibit shall remain fixed
     at the level indicated in Section 1 of this Exhibit, unless modified
     pursuant to Section 2 of this Exhibit.

6.b. The energy rate contained in Section 2.b. (ii) of this Exhibit shall be
     adjusted on the first anniversary and each subsequent anniversary of the
     Commercial Operation Date of the Project based on a three year rolling
     average of the change in the Gross National Product Deflator during the
     prior calendar year. The adjustment shall be calculated as follows:

     R(n) = (((I(n-l)/I(n-2)+(I(n-2)/I(n-3))+(I(n-3)/I(n-4))/3) R(n-1)

     R =    the indexed rate

     I =    the absolute level of the appropriate year index

     n =    the calendar year in which the adjustment takes place.

     In no event shall R(n) exceed a 5.5 percent increase for any three year
     rolling average.

     The capacity rates contained in Section 2.c (ii) of this Exhibit shall
     remain fixed at the level indicated in Section 2.c (ii) of this Exhibit,
     unless modified pursuant to Section 2 of this Exhibit.

                                                                   ATTACHMENT #3
                                                                       EXHIBIT E
                                                                 AMENDMENT NO. 1
                                                                     Page 1 of 4

                           SAMPLE BILLING CALCULATIONS

This example is for purposes of illustrating billing under the rate schedule
contained in this Agreement only, and does not supplement or amend the terms of
the Agreement to which it is attached.

1.   If the Project qualified for payment under Section 8(d) of this Agreement,
     the following payment method is applicable:
     Assume: a.     On-peak generation is 3,123,000 kWh.
             b.     Mid-peak generation is 6,246,000 kWh.
             c.     Off-peak generation is 5,621,400 kWh.
             d.     The energy and capacity was delivered during the
                    First Contract Year for the March billing period.
             e. o   2/3 of the energy will be paid at the following rates:
                    On-peak Exhibit D 2.b.(i) energy rate is $.02560/kWh.
                    Mid-peak Exhibit D 2.b.(i) energy rate is $.02484/kWh.
                    Off-peak Exhibit D 2.b.(i) energy rate is $.02244/kWh.
                o   1/3 of the energy will be paid at the following rate:
                    On-peak Exhibit D 2.b.(i) energy rate is $.03545/kWh.
                    Mid-peak Exhibit D 2.b.(i) energy rate is $.03440/kWh.
                    Off-peak Exhibit D 2.b.(i) energy rate is $.03108/kWh.

             f. o   2/3 of the capacity will be paid at the following rate:
                    Exhibit D 2.c.(i) capacity rate is $20.25/kW month.
                o   1/3 of the capacity will be paid at the following rate:
                    Exhibit D 2.c.(ii) capacity rate is $14.62/kWh.
             g.     There were 465 mid and on-peak hours during the billing
                    period.

     Calculation of the Energy Payment:

     The energy payment will equal the sum of the products of on-peak, mid-peak,
     and off-peak generation kilowatt hour values and the energy rate prorated
     at the different rates specified above.
     On-peak  =   2/3 x 3,123,000 kWh x $.02560 =   $ 53,299.20
     Mid-peak =   2/3 x 6,246,000 kWh x $.02484 =   $103,433.76

                                                                   ATTACHMENT #3
                                                                       EXHIBIT E
                                                                 AMENDMENT NO. 1
                                                                     Page 2 of 4

Off-peak = 2/3 x 5,621,400 kWh x $.02244 = $ 84,096.14
On-peak  = 1/3 x 3,123,000 kWh x $.03545 = $ 36,903.45
Mid-peak = 1/3 x 6,246,000 kWh x $.03440 = $ 71,620.80
Off-peak = 1/3 x 5,621,400 kWh x $.03108 = $ 58.237.70
                                           -----------
Total Energy Payment                       $407,591.05

Calculation of Capacity Payment:

The capacity payment will be prorated at the rates specified above. The capacity
payment will equal the lesser of a) the product of the Capacity Rate and the kWh
generated during the Peak Period hours, divided by the number of Peak Period
hours or b) the product of the Capacity Rate and Peak Period Capacity Value of
19,100 kW for the March Billing Period.

          1)   o $20.25/kW x 2/3 x 9,369,000 kWh / 465 = $272,003.23

               o $14.62/kW x 1/3 x 9,369,000 kWh / 465 = $ 98,189.81

          2)   o $20.25/kW x 2/3 x 19,100 kW = $257,850.00

               o $14.62/kW x 1/3 x 19,100 kW = $ 93,080.67

               Capacity Payment                $350,930.67

          Calculation of Total Payment:

          Total Payment will equal the sum of the capacity payment and energy
          payment.

          Total Payment = $407,591.05 + $350,930.67 = $758,521.72

     2.   If the Project qualified for payment under Section 8 (b) of this
          Agreement, the following payment method is applicable:

                                                                   ATTACHMENT #3
                                                                       EXHIBIT E
                                                                 AMENDMENT NO. 1
                                                                     Page 3 of 4

          Assume: a.   On-peak generation is 458,333 kWh.

                  b.   Mid-peak generation is 825,000 kWh.

                  c.   Off-peak generation is 550,000 kWh.

                  d.   On-Peak Exhibit C capacity rate is $.00873/kWh and
                       energy rate is $.02402/kWh.

                  e.   Mid-peak Exhibit C capacity rate is $.00782/kWh and
                       energy rate is $.02378/kWh.

                  f.   Off-peak Exhibit C capacity rate is $.00461/kWh and
                       energy rate is $.02022/kWh.

Calculation of Capacity Payment:

The capacity payment will equal the sum of the products of on-peak, mid-peak,
and off-peak generation kilowatt hour values and their respective rates.

On-peak  = 458,333 kWh x $.00873 = $ 4,001.25

Mid-peak = 825,000 kWh x $.00782 = $ 6,451.50

Off-peak = 550,000 kWh x $.00461 = $ 2,535.50

Capacity Payment                   $12,988.25

Calculation of Energy Payment:

The energy payment will equal the sum of the products of on-peak, mid-peak, and
off-peak generation kilowatt hour values and their respective rates.

On-peak  = 458,333 kWh x $.02402 = $11,009.16

Mid-peak = 825,000 kWh x $.02378 = $19,618.50

Off-peak = 550,000 kWh x $.02022 = $11,121.00
                                   ----------
Energy Payment                     $41,748.66

                                                                   ATTACHMENT #3
                                                                       EXHIBIT E
                                                                 AMENDMENT NO. 1
                                                                     Page 4 of 4

Calculation of Total Payment:

Total Payment will equal the sum of the capacity payment and energy payment.

Total Payment = $12,988.25 + 41,748.66 = $54,736.91

                         BRADY POWER PROJECT - Schedule

                                    [GRAPHIC]

________ POWER PARTNERS:

_______ GEOTHERMAL POWER
_______, LIMITED PARTNERSHIP,
_________ general partner

_________ Power Company,
_________ general partner

_____ /s/ Illegible
      ----------------------------------
_____ __oldenhersh, President
_______ __/10/91

By: ESI BH Limited Partnership,
         a general partner

By: /s/ Illegible
    ------------------------------------

By: Larry K. Carpenter, President
    Date: 12-9-91

SIERRA PACIFIC POWER COMPANY

By: /s/ Gerald W. Canning
    ------------------------------------
    Gerald W. Canning, Vice President
           Electric Operations
    Date: 12/20/92

--------
  APPVD.
--------
CD   SRC
--------

--------

Amendment No. 1 to Exhibit __
To Long Term Agreement ___ Purchase and Sale of Electricity Between Sierra
Pacific Power Company and Brady Power Partners
Page 2 of 2
Effective Upon Execution

                                                                       EXHIBIT G
                                                                       1 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                         First Revised Sheet P.S.C.N. No. 50
                                       Cancelling Original Sheet P.S.C.N. No. 50

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

                                   Rule No. 16

             SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (b)  Underground Service from Underground System (Continued)

               (1)  New Underground Service Installations (Continued)

                    (A)  the Applicant shall (Continued)

                              transformer vault, pull box, or other duct
                              termination facilities,

                         2.   perform the necessary trenching, backfill, and
                              paving for the service lateral,

                         3.   furnish and install any select backfill materials
                              required,

                         4.   furnish, install, and maintain, at his expense,
                              any specified conduit or duct from the transformer
                              vault, pull box, or other duct termination
                              facilities to the service connection point,

                         5.   permit the Utility to use the trench and any
                              conduit or duct system on his premises for the
                              purpose of housing the Utility's service
                              conductors or cables,

                         6.   pay to the Utility the cost of any conductors or
                              cables required between the service connection
                              point and the duct termination facilities in
                              addition to that provided by the Utility in
                              Section A.2.(b).(l). (B).6. hereof, and

                         7.   provide and maintain, at his expense, any
                              necessary outdoor termination enclosures.

                    (B)  the Utility shall

                         1.   specify the number, size and location of the
                              transformer vaults, pull boxes, or other duct
                              termination facilities,

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       2 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                         First Revised Sheet P.S.C.N. No. 51
                                       Cancelling Original Sheet P.S.C.N. No. 51

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

                                   Rule No. 16

             SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (b)  Underground Service from Underground System (Continued)

               (1)  New Underground Service Installations (Continued)

                    (B)  the Utility shall (Continued)

                         2.   designate the location of the service-connection
                              point at or near the property line of Applicant,

                         3.   specify the number, size, type and manner of
                              installation of conduit or duct systems on
                              Applicant's premises,

                         4.   specify the size of the conductors or cables to be
                              installed,

                         5.   install the conductors or cables from the service
                              connection point to the duct termination
                              facilities, and

                         6.   furnish and maintain, at its expense, all
                              conductors or cables required for installation
                              between the service connection point and the duct
                              termination facilities for a distance of one
                              hundred (100) feet or less.

                    (C)  the conductors or cables shall be terminated as
                         follows:

                         1.   Secondary service (480 volts or less). The
                              conductors or cables shall terminate in the
                              service terminating pull section of the
                              Applicant's switchgear or in a pull box or other
                              terminating facilities furnished and installed by
                              the Applicant.

                         2.   Primary service (2,400 volts or more). The
                              conductors or cables shall terminate in the
                              service terminating pull section of the
                              Applicant's switchgear or in a room, vault or
                              other suitable enclosure.

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       3 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                        Second Revised Sheet P.S.C.N. No. 52
                                  Cancelling First Revised Sheet P.S.C.N. No. 52

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (b)  Underground Service from Underground System (Continued)

               (2)  Underground Service Installations Replacing Existing
                    Overhead Services

                         In those instances and in those areas where an existing
                    overhead distribution system is replaced by an underground
                    distribution system, underground service connections will be
                    supplied in the same manner and subject to the same
                    conditions as for new installations under Section
                    A.2.(b).(l). above.

          (c)  Underground Services from Overhead Systems

               (1)  New Underground Service Installations

                         Upon a bona fide application for underground service
                    from an overhead system to an Applicant's premises, an
                    underground service connection will be provided by the
                    Utility in accordance with the following provisions:

                    (A)  the Applicant shall

                         1.   provide and maintain, at his expense, any required
                              transformer vault, pull box, or other duct
                              termination facilities,

                         2.   perform the necessary trenching, backfill, and
                              paving on his property and on the Utility easement
                              or right-of-way to the pole,

                         3.   furnish and install any select backfill materials
                              required,

                                   (Continued)

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

ISSUED:    April 17, 1970           Issued By:
                                  Neil W. Plath
EFFECTIVE: June 5, 1970             President

                                                                       EXHIBIT G
                                                                       4 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                         First Revised Sheet P.S.C.N. No. 53
                                       Cancelling Original Sheet P.S.C.N. No. 53

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (c)  Underground Services from Overhead Systems (Continued)

               (1)  New Underground Service Installations (Continued)

                    (A)  the Applicant shall (Continued)

                         4.   furnish, install, and maintain, at his expense,
                              any specified conduit or duct from the transformer
                              vault, pull box or other duct termination
                              facilities to the riser,

                         5.   furnish and install, at his expense, an
                              underground riser conduit to a point eight feet
                              above the ground on the designated pole,

                         6.   furnish the riser conduit and the required
                              protective coverings, attachments and terminals to
                              complete the riser installation,

                         7.   permit the Utility to use the trench and any
                              conduit and duct system on his premises for the
                              purpose of housing the Utility's service
                              conductors or cables,

                         8.   pay to the Utility the cost of any conductors or
                              cables required between the service connection
                              point on the pole and the duct termination
                              facilities in addition to that provided by the
                              Utility in Section A.2.(c). (1).(B).8. hereof, and

                         9.   provide and maintain, at his expense, any
                              necessary outdoor termination enclosures.

                    (B)  the Utility shall

                         1.   specify the number, size and location of the
                              transformer vaults, pull boxes or other duct
                              termination facilities,

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       5 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                         First Revised Sheet P.S.C.N. No. 54
                                       Cancelling Original Sheet P.S.C.N. No. 54

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (c)  Underground Services from Overhead Systems (Continued)

               (1)  New Underground Service Installations (Continued)

                    (B)  the Utility shall (Continued)

                         2.   designate the pole or location of such pole where
                              the service connection will be made,

                         3.   specify the number, size, type and manner of
                              installation of conduit or duct systems on
                              Applicant's premises,

                         4.   specify the number, size and type of riser
                              together with associated protective coverings and
                              attachments,

                         5.   specify the size of conductors or cables to be
                              installed,

                         6.   install the conductors or cables from the service
                              connection point on the pole to the duct
                              termination facilities,

                         7.   install the remaining portion of the riser, and

                         8.   furnish and maintain, at its expense, all
                              conductors or cables required for installation
                              between the service connection point on the pole
                              and the duct termination facilities for a distance
                              of one hundred (100) feet or less.

                    (C)  the conductors or cables shall be terminated as
                         follows:

                         1.   Secondary service (480 volts or less). The
                              conductors or cables shall terminate in the
                              service terminating pull section of the
                              Applicant's switchgear or in a pull box or other
                              termination facilities furnished and installed by
                              the Applicant.

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       6 of 12

SIERRA PACIFIC POWER COMPANY                Second Revised Sheet P.S.C.N. No. 55
        RENO, NEVADA              Cancelling First Revised Sheet P.S.C.N. No. 55

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     2.   Underground Service Connections (Continued)

          (c)  Underground Services from Overhead Systems (Continued)

               (1)  New Underground Service Installations (Continued)

                    (C)  the conductors or cables shall be terminated as
                         follows: (Continued)

                         2.   Primary service (2,400 volts or more). The
                              conductors or cables shall terminate in the
                              service terminating pull section of the
                              Applicant's switchgear or in a room, vault or
                              other suitable enclosure.

               (2)  Underground Service Installations Replacing Existing
                    Overhead Services

                         Upon a bona fide application for replacement of an
                    existing overhead service with an underground service to an
                    Applicant's premises, an underground service connection will
                    be supplied in the same manner and subject to the same
                    conditions as for new installations under Section A.2.
                    (c).(l). above.

          (d)  Replacement or Reinforcement of Existing Underground Services

                    Whenever, in the judgement of the Utility, an underground
               service requires replacement or reinforcement, such replacement
               or reinforcement will be made in the same manner and subject to
               the same conditions as for new installations under Section A.2.
               (b). (1). hereof.

     3.   Number of Services to be Installed

               The Utility will not install more than one service, either
          overhead or underground, for the same voltage and phase classification
          for any one building or group of buildings on a single premises,
          except that separate services may be installed for separate buildings
          or groups of buildings

                                   (Continued)

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

ISSUED: April 17, 1970              Issued By:
                                  Neil W. Plath
EFFECTIVE: June 5, 1970             President

                                                                       EXHIBIT G
                                                                       7 of 12

SIERRA PACIFIC POWER COMPANY                Second Revised Sheet P.S.C.N. No. 56
        RENO, NEVADA              Cancelling First Revised Sheet P.S.C.N. No. 56

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     3.   Number of Services to be Installed (Continued)

          where necessary for the operating convenience of the Utility. Where
          required by law, local ordinance, and if at Customer's convenience;
          where the Utility installs more than one metered service, each meter
          will be billed separately. Where more than one class of service is
          required for a Customer and is to be supplied from the same pole,
          manhole or service box, the service outlets are to be located as close
          together as practicable.

     4.   Connection of Applicant's Service to Utility Lines

               Only authorized employees of the Utility will be permitted to
          connect the Applicant's service lateral and the Applicant's
          terminating facilities to, or disconnect the same from the Utility's
          electric lines.

     5.   Meters and Associated Equipment

          (a)  General

                    The Utility will, at its own expense, install a suitable
               meter on an Applicant's premises in a location furnished by him
               and approved by the Utility, which location shall, at all
               reasonable times, be accessible for reading, testing and
               maintaining the meter. No rent or other charge shall be made by
               the Applicant for the use of this location.

          (b)  Multiple-Occupancy Buildings

                    In multiple-occupancy buildings where a number of meters are
               required to measure the electricity supplied, all meters will be
               located at a central point and each meter socket or panel will be
               clearly marked to indicate the particular location supplied
               through it.

                    In buildings which are divided into two or more stores or
               other commercial premises, meters may be installed in the
               separate premises provided no adjacent alleyway, common basement
               or other location accessible to all the tenants and suitable for
               the installation of

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       8 of 12

SIERRA PACIFIC POWER COMPANY
        RENO, NEVADA                             Original Sheet P.S.C.N. No. 56A

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     5.   Meters and Associated Equipment (Continued)

          (b)  Multiple-Occupancy Buildings (Continued)

               a group of meters exist. In such buildings, all wiring from the
               Utility's point of delivery to the individual meters shall be in
               rigid conduit.

          (c)  Sealing of Meters

                    All meters will be sealed by the Utility at the time of
               installation and no seal shall be altered or broken except by one
               of its authorized employees.

          (d)  Equipment Furnished by Customer

                    All service switches, meter sockets, meter and instrument
               transformer housings, cutouts and similar devices, irrespective
               of voltage, required in connection with a service and meter
               installation on a Customer's premises shall be furnished,
               installed and maintained by the Customer in accordance with, the
               Utility's requirements.

          (e)  Equipment Furnished by Utility

                    The Utility will furnish and install the necessary
               instrument transformers, test facilities and meters. The Utility
               will furnish the metering enclosures when in the opinion of the
               Utility it appears necessary to locate metering equipment at a
               point that is not accessible to the Customer.

          (f)  Master Meters

                    A master meter will be furnished and installed by the
               Utility upon application by the owner or lessee of any buildings
               where the floors (or portions thereof) or rooms or groups of
               rooms are rented separately and where electric energy is to be
               metered and resold by said owner or lessee to the individual
               tenants as provided in Rule No. 18, Supply To Separate Premises
               and Resale. In such cases, the said owner or lessee shall
               furnish, install, maintain and test the submeters.

                                   (Continued)

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

ISSUED: June 23, 1966               Issued By:
                                  Neil W. Plath
EFFECTIVE: October 3, 1966          President

                                                                       EXHIBIT G
                                                                       9 of 12

SIERRA PACIFIC POWER COMPANY                First Revised Sheet P.S.C.N. No. 56B
        RENO, NEVADA                  Cancelling Original Sheet P.S.C.N. No. 56B

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     6.   Transformer Installations on Applicant's Premises

          (a)  General

                    In those instances where the Utility, for aesthetic,
               economic or engineering reasons, desires to install transformers
               on Applicant's premises, the Applicant shall furnish a
               satisfactory right-of-way for the high voltage primary service
               conductors and shall provide adequate space for the transformer
               installation. Right-of-way and space provisions must be such that
               legal clearances from adjacent structures can be maintained and
               the vault, transformer room, or enclosures shall conform with all
               applicable laws of the State of Nevada, and/or municipal
               regulations, and/or regulations of other public bodies having
               jurisdiction thereof, and shall meet with the approval of the
               Utility.

          (b)  Installations of 75 Kva and Larger

               (1)  The Utility will not furnish pole-type structures.

               (2)  Where transformers and associated equipment or appurtenances
                    are to be located in a fireproof vault or room in a building
                    (or structure), the Applicant shall, at his expense, provide
                    and maintain such vault or room as specified by the Utility.
                    Applicant shall also furnish and install, at his expense,
                    all secondary equipment and material necessary to receive
                    service at the secondary terminals of transformer(s) or as
                    otherwise specified by the Utility. The Utility will, at its
                    expense, complete the installation.

               (3)  Where transformers and associated equipment or appurtenances
                    are to be located outdoors, the Applicant shall, at his
                    expense, provide and maintain, as specified by the Utility,
                    a concrete pad or foundation and suitable enclosure, if
                    required. The Applicant shall also furnish and install, at
                    his expense, all secondary equipment and material necessary
                    to receive service at the secondary terminals of the
                    transformer(s) or as otherwise specified by the Utility. The
                    Utility will, at its expense, complete the installation.

                                   (Continued)

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

ISSUED: April 17, 1970             Issued By:
                                  Neil W. Plath
EFFECTIVE: June 5, 1970             President

                                                                       EXHIBIT G
                                                                       10 of 12

SIERRA PACIFIC POWER COMPANY                First Revised Sheet P.S.C.N. No. 56C
        RENO, NEVADA                  Cancelling Original Sheet P.S.C.N. No. 56c

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

A.   Service Installation (Continued)

     6.   Transformer Installations on Applicant's Premises (Continued)

          (c)  Installations of Less Than 75 KVA

               (1)  The Utility will erect a pole-type transformer structure, at
                    its expense, and service from this structure will be
                    supplied as specified by the Utility.

               (2)  In those instances where the Applicant has provided a
                    fireproof vault or room, at his expense, the installation
                    shall be made in accordance with Section A.6.(b).(2). above.

               (3)  In those instances where the Applicant has provided a
                    concrete pad or foundation, the installation will be made in
                    accordance with Section A.6.(b).(3). above.

B.   Ownership

          The transformers, meters, service wires, appliances, fixtures and
     other facilities furnished by the Utility at its own expense and located
     wholly or partially upon a Customer's premises for the purpose of
     delivering electric energy to the Customer will at all times be and remain
     the property of the Utility which shall have the right to repair or replace
     them at any time or to remove them after service to the Customer has been
     discontinued.

          Such equipment may also be used to supply other Customers whether or
     not on the same premises, provided the proper rights-of-way have been
     obtained.

          No rent or other charge whatsoever shall be made by the Customer
     against the Utility for placing or maintaining said transformers, meters,
     service wires, appliances, fixtures, etc. upon the Customer's premises.

          The Customer shall exercise reasonable care to prevent the facilities
     of the Utility upon said premises from being damaged or destroyed, and
     shall refrain from interfering with same, and, in case any defect therein
     shall be discovered, shall notify the Utility thereof.

                                   (Continued)

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

ISSUED: April 17, 1970             Issued By:
                                  Neil W. Plath
EFFECTIVE: June 5, 1970             President

                                                                       EXHIBIT G
                                                                       11 of 12

SIERRA PACIFIC POWER COMPANY                First Revised Sheet P.S.C.N. No. 56D
        RENO, NEVADA                  Cancelling Original Sheet P.S.C.N. No. 56D

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

C.   Maintenance

          The Utility will be responsible for the maintenance of its own
     property only, and the Customer shall be responsible for the maintenance of
     all other property required for the receipt of electric energy from the
     Utility.

D.   Right of Access

          Upon application for electric service and the establishment of service
     pursuant thereto, the Customer shall be deemed to grant to the Utility and
     its assigns, to whatever extent the Customer may be empowered to make such
     grant, an irrevocable easement upon and through the Customer's premises for
     the location of the facilities of the Utility required to provide service.
     Any such grant from the owner of the premises serviced shall be deemed to
     be an easement running with the land, and shall bind his heirs and assigns.

          The Utility will, at all reasonable times, have the right of access to
     a Customer's premises for any purpose normally connected with the
     furnishing of electric energy and the exercise of the rights secured to it
     by law or these rules.

E.   Responsibility for Loss or Damage

          The Utility will not be responsible for any loss or damage caused by
     any negligence or wrongful act of a Customer or Customer's authorized
     representatives in installing, maintaining, or operating the receiving
     facilities or utilizing equipment for which electric energy is being
     supplied.

          The Customer shall, at his sole risk and expense, furnish, install,
     inspect and keep in good and safe condition all electrical wires, lines,
     machinery and apparatus of any kind or character which may be required for:
     (1) receiving electric energy from the lines of the Utility, regardless of
     the location of the transformers, meters or other equipment of the Utility;
     and (2) applying and utilizing such energy, including all necessary
     protective appliances and suitable housing therefor.

          The Customer shall also transmit and deliver and be solely responsible
     for the transmission and delivery of all electric energy over or through
     Customer's wires and equipment, regardless of the place where such electric
     energy may be transformed or metered.

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

ISSUED: July 27, 1967               Issued By:
                                  Neil W. Plath
EFFECTIVE: September 20, 1967       President

                                                                       EXHIBIT G
                                                                       12 of 12

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada                5th Revised   P.S.C.N. Sheet No. 56E
Tariff No. Electric No. 1      Cancelling   4th Revised   P.S.C.N. Sheet No. 56E

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

                                   Rule No. 16

              SERVICE CONNECTIONS, METERS AND CUSTOMER'S FACILITIES
                                   (Continued)

     F.   Remote Metering

               Remote metering is available to any Customer with 120/240 volt
          single phase service who does not desire to comply with Section D,
          Right of Access, hereto, relative to meter reading.

               The Customer will be required to pay Utility $100.00, in advance,
          for the cost of installing the facilities necessary to provide remote
          metering. The remote metering equipment will remain the property of
          Utility, and Utility will maintain the equipment.

               Utility will require a minimum of two (2) annual inspections of
          the meter and remote register for verification of the meter readings.

               If at any time there should exist a difference between the meter
          reading and the remote register reading, the meter reading will be
          considered as the proper basis for purposes of billing. If a meter
          test is required, it will be done in compliance with Rule No. 17.

     G.   Customer's Responsibilities

          1.   Utility Owned Facilities

               Utility property installed on the premises served for the purpose
               of measuring or supplying service to a customer is placed there
               under the Customer or property owner's protection. The Customer
               or property owner will be held responsible for the breaking of
               seals, tampering or interfering with Utility's meter or meters or
               other equipment of Utility placed under their protection. Only
               authorized employees of Utility will be allowed to make repairs
               or adjustments to meters or other apparatus belonging to Utility.
               Where such repairs or adjustments are necessary, a charge shall
               be made to the customer or property owner as appropriate, in
               addition to actual material costs. See Schedule SC, PSCN No. 63C.

     H.   Tax Liability on Customer Contributions

               Contributions by customers of or for facilities or equipment
          provided under this rule will be increased by the appropriate tax
          liability factor from Section C.5 of Rule No. 9. to cover the
          Utility's tax liability on such contributions. Such tax liability will
          be paid in cash.

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

Issued: 11/28/88

                                   Issued By:
Effective:  11/28/88            Austin W. Stedham
                                    President

Advice No.: 273-E
            Amended
--------------------------------------------------------------------------------

                                                                       EXHIBIT H
                                                                       1 of 3

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada                 6th Revised   P.S.C.N. Sheet No. 57
Tariff No. Electric No. 1      Cancelling    5th Revised   P.S.C.N. Sheet No. 57

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

                                   RULE NO. 17

               METER TESTS AND ADJUSTMENT OF BILLS FOR METER ERROR

     A.   Tests

          1.   Facilities

               The utility shall provide or have access to a facility to
               determine the accuracy of its meters.

          2.   On Customer Request

               The utility shall test the meter of a customer upon his request.

               No charge will be made for performing the test once during any 12
               month period. The utility may charge the customer a fee, as set
               forth in Schedule SC, PSCN No. 63C, for any additional test
               conducted during the period.

               The customer may be present and may request a qualified
               representative of the Commission be present at the time a test is
               conducted.

               If a meter is tested at the request of a customer, the utility
               shall, within a reasonable time after the test:

               a.   Provide the customer with a written statement of the results
                    of the test.

               b.   Notify the customer in writing if the meter is replaced or
                    repaired.

               The utility will prepare and maintain a record of the results of
               each test conducted pursuant to this section. The record will
               include:

               a.   The name and address of the customer.

               b.   The meter number.

               c.   The type of meter.

               d.   The type of test.

               e.   The date on which the test was conducted.

               f.   The results of the test.

               g.   A description of any action taken as a result of the test.

                                        (Continued)

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

Issued: 1/16/90

                                    Issued By:
Effective: 1/16/90              Austin W. Stedham
                                    President

Advice No.: 292-E

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

                                                                       EXHIBIT H
                                                                       2 of 3

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada                5th Revised   P.S.C.N. Sheet No. 58
Tariff No. Electric No. 1      Cancelling   4th Revised   P.S.C.N. Sheet No. 58

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

                                   RULE NO. 17

               METER TESTS AND ADJUSTMENT OF BILLS FOR METER ERROR
                                   (Continued)

     B.   Adjustment of Bills for Meter Error

          1.   If a meter is tested and found to be inaccurate by more than two
               percent (2%), the bill for service of any customer affected must
               be adjusted as provided in this section.

          2.   Except as otherwise provided in Section B.3., if the meter has:

               a.   Slow Metering:

                    Under-recorded the usage of electric energy. The adjustment
                    must be made only for the period of the most recent three
                    (3) months of usage.

               b.   Fast Metering:

                    Over-recorded usage, the adjustment must be made only for
                    the period of the most recent six (6) months of usage.

               c.   Non-Registering Meters:

                    Upon test, been found to be non-registering, utility shall
                    bill the customer for the estimate of consumption not
                    registered for either the period the meter was in use at
                    such customer's premises, or the preceding three (3) months,
                    whichever is shorter.

          3.   Unauthorized Service

               If the utility establishes that the meter has been tampered with
               or used without authorization, the billing adjustment must be
               calculated for a period not to exceed the most recent six (6)
               months of usage or the date on which the tampering or
               unauthorized use began, whichever is greater.

                                   (Continued)

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

Issued: 1/16/90

                                    Issued By:
Effective: 1/16/90              Austin W. Stedham
                                    President

Advice No.: 292-E

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

                                                                       EXHIBIT H
                                                                       3 of 3

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada               2nd Revised    P.S.C.N. Sheet No. 58A
Tariff No. Electric  No. 1      Cancelling 1st Revised    P.S.C.N. Sheet No. 58A

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

                                   RULE NO. 17

               METER TESTS AND ADJUSTMENT OF BILLS FOR METER ERROR
                                   (Continued)

B.   Adjustment of Bills for Meter Error (Continued)

     4.   Underpayment

          A customer who, because of an adjustment to his bill, owes the utility
          money for service may pay that amount over a three (3) month period.

     5.   Overpayment

          The utility shall credit the account of a customer who was overcharged
          because of an inaccurate meter not later than thirty (30) days after
          the overcharge is determined.

     6.   Calculation of Billing Adjustment

          Bills for this purpose shall be based upon:

          a.   Customer's prior use;

          b.   Customer's subsequent use correctly metered;

          c.   Utility's experience with other customers of the same class; and

          d.   The general characteristics of customer's operations.

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

Issued: 1/16/90
                                    Issued By:
Effective: 1/16/90              Austin W. Stedham
                                    President
Advice No.: 292-E

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

                                                                       EXHIBIT I
                                                                       1 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada               4th Revised    P.S.C.N. Sheet No. 67D
Tariff No. Electric  No. 1      Cancelling 3rd Revised    P.S.C.N. Sheet No. 67D

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION

APPLICABILITY

     Service hereunder is applicable to any Customer where all or part of the
electrical requirements can be supplied from a cogeneration or small power
production source which meets the criteria for a Qualifying Facility set forth
in Subpart B, Sections 292.201-292.207 of the FERC rules (45 Fed. Reg. 17959),
and which service is elected by the Customer to be billed under the net metering
option described in Rule No. 15, paragraph B.3.a. QFs billed under the seperate
metering option of Rule No. 15, paragraph B.3.b. will be billed under the
appropriate rate schedule for regular service.

     The cogeneration or small power production source may be connected for: (1)
parallel operation with service of Utility, or (2) isolated operation with
standby or breakdown service provided by Utility by means of a double-throw
switch.

     This schedule is limited to Customers having a maximum total demand equal
to or greater than fifty (50) kilowatts and where another schedule is not
specifically applicable.

     This tariff will be effective until changed with the approval of the Public
Service Commission of Nevada in Sierra Pacific Power Company's first electric
general rate case filed after 3/1/91.

TERRITORY

     Entire Nevada service area, as specified.

RATES

     Customer Charge

     Per meter per month:                                                $700.00

                                   (Continued)

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

Issued: 03/01/91
                                      Issued By:
Effective: 03/01/91              William L. Keepers
                                      President
Advice No.: 298-E

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

                                                                       EXHIBIT I
                                                                       2 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada               4th Revised    P.S.C.N. Sheet No. 67E
Tariff No. Electric  No. 1      Cancelling 3rd Revised    P.S.C.N. Sheet No. 67E

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

RATES (Continued)

     Fixed Standby Demand Charge

        For each kilowatt of contract demand              $3.47

     Additional Variable Demand Charge

        For each kilowatt of maximum total demand
           in excess of the contract demand               $3.47

     Variable Demand Charge

        For each kilowatt of On-Peak billing demand       $3.51
        For each kilowatt of Mid-Peak billing demand      $1.76

     Energy Charge

                                       Base Tariff   Base Tariff       Total
                                      General Rate   Energy Rate   Energy Charge
                                      ------------   -----------   -------------
     Winter
        All On-Peak  kWh, per kWh        $.01358       $.02789        $.04147
        Plus all Mid-Peak kWh,
           per kWh                       $.01138       $.02789        $.03927
        Plus all Off-Peak kWh,
           per kWh                       $.00495       $.02789        $.03284

     Summer
        All On-Peak kWh, per kWh         $.01270       $.02789        $.04059
        Plus all Off-Peak kWh,
           per kWh                       $.00806       $.02789        $.03595

     Deferred Energy Accounting
        Adjustment

        All kWh per kWh
           (02/01/90  - 01/31/91)                                     $.00113

                                   (Continued)

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

Issued: 9/1/90
                                   Issued By:
Effective: 9/1/90              Austin W. Stedham
                                     President
Advice No.: 301-E
--------------------------------------------------------------------------------

                                                                       EXHIBIT I
                                                                       3 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              Original _____ P.S.C.N. Sheet No. 67F
Tariff No. Electric No. 1      Cancelling ______________ P.S.C.N. Sheet No. ___

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

RATES (Continued)

     Power Factor Adjustment

          Credit (or charge) at the rate of $.0014 per kvarh for all actual
          kvarh less than (or greater than) equivalent kvarh at a 90% power
          factor level per Special Condition 5.

     Voltage and Transformer Adjustment

          Where service is delivered directly from a primary distribution or
          transmission system, the Customer, demand and energy charges shall be
          decreased as follows:

                                                       Primary
                                                     Distribution   Transmission
                                                     ------------   ------------
     a.   Where service is metered at or
          compensated to the delivery point              1.25%          7.50%

     b.   Where customer owns and maintains all
          equipment required for transformation
          from the delivery voltage                      1.25%          7.50%

     c.   Where both a) and b) exist                     2.50%         10.00%

     d.   Where neither a) nor b) exist                  None           5.00%

     Late Charge

          1% on any amount in arrears from previous billings.

     Tax Adjustment Charge

          2% of total bill within incorporated area (3/4 of 1% for City of
          Gabbs) or as designated in specific franchise agreements.

                                   (Continued)

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

Issued: 2/6/89
                                    Issued By:
Effective: 2/6/89               Austin W. Stedham
                                    President
Advice No.: 281-E

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

                                                                       EXHIBIT I
                                                                       4 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              Original _____ P.S.C.N. Sheet No. 67G
Tariff No. Electric No. 1      Cancelling ______________ P.S.C.N. Sheet No. ___

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

MINIMUM CHARGE

     The minimum charge for service hereunder shall be the sum of the customer
charge, demand charges, energy charges, deferred energy accounting adjustment,
power factor adjustment, voltage and transformer adjustment, late charge and tax
adjustment charge.

SPECIAL CONDITIONS

     1.   A written contract will be required for service hereunder, for a
          minimum term of not less than five years.

     2.   Determination of Demand: The demand for any billing shall be defined
          as the maximum measured fifteen minute average kilowatt load in the
          billing period. In instances, however, where the use of energy by a
          Customer is intermittent or subject to violent fluctuations, a shorter
          time interval may be used and the demand determined from special
          measurements. At Utility's option, a thermal type of demand meter
          which does not reset after a definite time interval may be used for
          demand measurements.

     3.   Contract Demand: The contract demand for Customers requiring standby
          service for all of their self-generation capacity shall be the
          nameplate capacity, in kW, of connected self-generation capacity for
          which Utility will standby. In the event that measured output from the
          self-generation equipment in any month exceeds the previously
          established contract demand, Utility may revise the contract demand to
          this higher measured amount.

                                   (Continued)

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

Issued: 2/6/89
                                    Issued By:
Effective: 2/6/89               Austin W. Stedham
                                    President
Advice No.: 281-E

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

                                                                       EXHIBIT I
                                                                       5 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              1st Revised     P.S.C.N. Sheet No. 67H
Tariff No. Electric No. 1      Cancelling Original        P.S.C.N. Sheet No. 67H

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

SPECIAL CONDITIONS (Continued)

          The contract demand for Customers requiring standby service for less
          than all of their self-generation capacity shall be the maximum load
          that the Customer is expected to place on the Utility's system under
          normal standby operating conditions, as determined by the Utility at
          the time the service contract is written or at such time as the
          Utility becomes aware that normal standby operating conditions have
          changed.

     4.   Maximum Total Demand: The maximum total demand for any billing period
          shall be the maximum (over the fifteen minute metering intervals) of
          the sum of metered demand for service provided by the Utility and the
          metered coincident output of the customer's self-generation equipment,
          less the Customer's coincident metered deliveries to the Utility.

     5.   On-Peak Billing Demand: The billing demand hereunder for any billing
          period shall be the greater of the current period's maximum metered
          demand for service provided by the Utility during the on-peak period;
          or twenty-five percent (25%) of the highest metered demand during the
          on-peak billing period established by the Customer during the
          preceding eleven (11) months. Demands imposed on the Utility's system
          during periods of scheduled maintenance arranged at the convenience of
          and with the approval of the Utility, will not be considered in
          determining the billing demand applicable to the assessment of
          generation and transmission demand charges.

                                   (Continued)

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

Issued: 03/01/91
                                    Issued By:
Effective: 03/01/91             William L. Keepers
                                    President

Advice No.: 298-E

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

                                                                       EXHIBIT I
                                                                       6 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              Original       P.S.C.N. Sheet No. 67I
Tariff No. Electric No. 1      Cancelling ____________   P.S.C.N. Sheet No. ___

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

                          EXPERIMENTAL SCHEDULE NO. FSS

                              FIRM STANDBY SERVICE

                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

SPECIAL CONDITIONS (Continued)

     6.   Mid-Peak Billing Demand: The billing demand hereunder for any billing
          period shall be the current period's maximum metered demand for
          service provided by the Utility during the mid-peak period. Demands
          imposed on the Utility's system during periods of scheduled
          maintenance arranged at the convenience of and with the approval of
          the Utility, will not be considered in determining the billing demand
          applicable to the assessment of generation and transmission demand
          charges.

     7.   When service is initiated under this schedule, the Customer charge
          will be established on the basis of the Utility's estimate of the
          Customer's highest monthly maximum total demand. If, in any month, the
          Customer's maximum total demand equals or exceeds 1,000 kW, the
          Customer will be billed the Customer charge for that level of service
          until twelve (12) consecutive months are experienced with the
          Customer's maximum total demand less than 1,000 kW.

     8.   The power factor adjustment shall be at a rate of $.0014 per kvarh.
          The rate shall be applied to the difference between actual kvarh and
          the kvarh equivalent to a ninety percent (90%) power factor level. If
          the actual kvarh are greater than kvarh equivalent to a ninety percent
          (90%) power factor, then the adjustment shall be a charge to the
          Customer. If the actual kvarh are less than kvarh equivalent to a
          ninety percent (90%) power factor, then the adjustment shall be a
          credit to the Customer. Kvarh equivalent to a 90% power factor level
          shall be estimated as .484 times total billed killowatthours during
          the billing period.

                                   (Continued)

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

Issued: 2/6/89
                                   Issued By:
Effective: 2/6/89               Austin W. Stedham
                                    President
Advice No.: 281-E

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

                                                                       EXHIBIT I
                                                                       7 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              1st Revised    P.S.C.N. Sheet No. 67J
Tariff No. Electric No. 1      Cancelling Original       P.S.C.N. Sheet No. 67J

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

                          EXPERIMENTAL SCHEDULE NO. FSS
                              FIRM STANDBY SERVICE
                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

SPECIAL CONDITIONS (Continued)

     9.   Utility retains the right to change its line voltage at any time,
          after reasonable advance notice to any Customer receiving a voltage
          and transformer adjustment. Such Customer then has the option to
          change his system so as to receive service at the new line voltage or
          to accept service (without discount) through transformers to be
          supplied by Utility.

     10.  Daily time periods will be based on Pacific Standard time and are
          defined as follows:

          Winter Period   On-Peak    5:01 p.m. to 10:00  p.m. daily
                          Mid-Peak   7:00 a.m. to 5:00 p.m. daily
                          Off-Peak   All Other Hours

          Summer Period   On-Peak    10:01 a.m. to 10:00 p.m. daily
                          Off-Peak   All Other Hours

          The winter period will consist of eight regularly scheduled billing
          periods for service provided in the months of October through May. The
          summer period will consist of four regularly scheduled billing periods
          for service provided in the months of June through September.

     11.  Included in the Energy Charge is a base unit energy cost as defined in
          General Order No. 21 and fully described on Schedule No. DEAA.

     12.  Included in the Base Tariff General Rate is $(.00007) per kilowatthour
          ($.00013 base rate and ($.00020) amortization rate) for recovery of
          expenses incurred in developing a plan for resources pursuant to NRS
          704.751.

                                   (Continued)

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

Issued: 04/01/90
                                      Issued By:
Effective: 04/01/90               Austin W. Stedham
                                      President
Advice No.: 297-E

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

                                                                       EXHIBIT I
                                                                       8 of 8

SIERRA PACIFIC POWER COMPANY
6100 Neil Road, Reno, Nevada              Original       P.S.C.N. Sheet No. 67K
Tariff No. Electric No. 1      Cancelling ____________   P.S.C.N. Sheet No. ___

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

                          EXPERIMENTAL SCHEDULE NO. FSS
                              FIRM STANDBY SERVICE
                     COGENERATION AND SMALL POWER PRODUCTION
                                   (Continued)

SPECIAL CONDITIONS (Continued)

     13.  Service hereunder is subject to the provisions of Rule No. 15.

     14.  The Customer will pay all costs of interconnection with the Utility,
          beyond the cost of the meter and service drop appropriate for the
          Customer in the absence of self-generation equipment. The Utility will
          install separate metering of the Customer's self-generating equipment
          at the Customer's expense. The Customer will furnish, install, and
          maintain all switches, sockets, housings, cutouts, and similar devices
          required in connection with the metering of the self-generating
          equipment in a location approved by the Utility, which location shall
          at all reasonable times be accessible for reading, testing, and
          maintaining the meter.

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

Issued: 2/6/89
                                   Issued By:
Effective: 2/6/89               Austin W. Stedham
                                    President
Advice No.: 281-E

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

                                                              EXHIBIT J - 1 of 5

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              1st Revised    P.S.C.N. Sheet No. 8
Tariff No. Electric No. __        Cancelling Original       P.S.C.N. Sheet No. 8

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

                                   Rule No. 2

                             DESCRIPTION OF SERVICE

A.   General

     1.   Service described hereunder may be obtained by any person or agency by
          making application in accordance with Rule No. 3 and, if required, by
          signing a contract in accordance with Rule No. 10. Each Applicant will
          also be required to establish credit in accordance with Rule No. 12.
          Applicant will be informed as to the conditions under which service
          will be established if the requested service requires a Utility
          installation beyond that specified for a service connection in Rule
          No. 16.

     2.   The type of service available at any particular location should be
          ascertained by inquiry at the local Utility office.

     3.   It is the responsibility of the Applicant to ascertain and comply with
          regulations of governmental entities having jurisdictional authority.

     4.   Alternating current service of approximately 60 hertz is regularly
          supplied.

     5.   Voltages referred to in these tariffs are nominal and refer either to
          voltage between energized conductors and ground, or to voltage between
          energized conductors.

B.   Service Delivery Voltages

     1.   The following are standard service voltages, however, not all voltages
          are or can be made available at a given service delivery point:

                                   (Continued)

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

Issued: 9/21/84
                                    Issued By:
Effective: 9/21/84                Joe L. Gremban
                                     President
Advice No.: 231-E

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

                                                              EXHIBIT J - 2 of 5

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              1st Revised    P.S.C.N. Sheet No. 9
Tariff No. Electric No. __        Cancelling Original       P.S.C.N. Sheet No. 9

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

                                   Rule No. 2

                             DESCRIPTION OF SERVICE
                                   (Continued)

B.   Service Delivery Voltages (Continued)

                                                       Transmission
               Distribution Voltages                     Voltages
--------------------------------------------------   ---------------
 Single-Phase       Three-Phase       Three-Phase
  Secondary          Secondary          Primary        Three-Phase
--------------------------------------------------   ---------------
120/240 3-Wire   120/240 4-Wire*    Contact local    Contact local
120/208 3-Wire*  120/208 Y 4-Wire   Utility office   Utility office.
                 277/480 Y 4-Wire

  *Limited availability - subject to Utility approval.

     2.   Voltages greater than 600 volts but less than 25,000 volts are defined
          as primary distribution voltages. Service at primary distribution
          voltages may be available on request subject to Utility approval.

     3.   Voltages of 25,000 volts and above are defined as transmission
          voltages. Service at transmission voltage may be available on request
          subject to Utility approval.

     4.   Where the Applicant desires voltage control within unusually close
          limit beyond that supplied by the Utility in the normal operation of
          its system, the Applicant, at his own expense, is responsible for
          installing, owning, operating, and maintaining any special or
          additional equipment on the load side of the point of delivery.

                                   (Continued)

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

Issued: 9/21/84
                                    Issued By:
Effective: 9/21/84                Joe L. Gremban
                                     President
Advice No.: 231-E

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

                                                              EXHIBIT J - 3 of 5

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              1st Revised   P.S.C.N. Sheet No. 10
Tariff No. Electric No. __        Cancelling Original      P.S.C.N. Sheet No. 10

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

                                   Rule No. 2

                             DESCRIPTION OF SERVICE
                                   (Continued)

C.   General Load Limitations

     1.   Single and Three-Phase Secondary Service

                         Service Configuration   Maximum
                         ---------------------    Demand
                           Nominal               -------
                           Voltage     Phase        kW
                         -------------------------------
                           120/240    1(phi)       150
                           120/208    1(phi)       150
                           120/208Y   3(phi)       *
                           120/240    3(phi)       *
                           277/480Y   3(phi)       *

*Contingent upon transformer KVA size limitations

Note: Not all of the above voltages are or can be made available at a given
     service location. It is the responsibility of the Applicant to consult the
     local Utility office to ascertain the service configuration(s) available at
     the location in question.

                                   (Continued)

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

Issued: 9/21/84
                                    Issued By:
Effective: 9/21/84                Joe L. Gremban
                                     President
Advice No.: 231-E

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

                                                              EXHIBIT J - 4 of 5

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              1st Revised   P.S.C.N. Sheet No. 11
Tariff No. Electric No. 1         Cancelling Original      P.S.C.N. Sheet No. 11

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

                                   Rule No. 2

                             DESCRIPTION OF SERVICE
                                   (Continued)

C.   General Load Limitations (Continued)

     2.   Load Balance

          A customer's connected load must be balanced as nearly as practicable
          between energized conductors. In no case shall the difference in
          amperage between two energized conductors on a secondary service
          exceed 10 percent or 50 amperes, whichever is greater. The difference
          between the load on a lighting phase of a four-wire delta service and
          the load on the power phases may exceed these limits.

     3.   Protective Devices

          a.   Loads connected to a service shall have sufficient protective
               devices, installed and maintained at the customer's expense, to
               prevent damage to equipment during routine conditions that may
               include sudden loss of voltage, sudden re-energization, opening
               of one or more phases, and voltage or current fluctuations or
               variations.

          b.   It is the responsibility of the customer to furnish, install, and
               maintain at his expense any protective devices necessary to
               coordinate with Utility's protective devices to avoid exposing
               other Utility customers to unnecessary service interruptions.

          c.   The connection and operation of customer owned generation
               facilities in parallel with the Utility's system will be governed
               by the requirements of Rule No. 15.

     4.   Interference With Service

          The customer shall not connect load to his service that introduces
          abnormal currents, voltages, and/or frequencies to the Utility's
          system or to communication facilities, or that interferes with a
          normally acceptable quality of service to any other customer. Upon
          notification by the Utility that one of the above conditions exist,

                                   (Continued)

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

Issued: 9/21/84
                                    Issued By:
Effective: 9/21/84                Joe L. Gremban
                                     President
Advice No.: 231-E

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

                                                              EXHIBIT J - 5 of 5

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              1st Revised   P.S.C.N. Sheet No. 12
Tariff No. Electric No. 1         Cancelling Original      P.S.C.N. Sheet No. 12

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

                                   Rule No. 2

                             DESCRIPTION OF SERVICE
                                   (Continued)

C.   General Load Limitations (Continued)

     4.   Interference With Service (Continued)

          the customer shall either discontinue use of the load causing the
          interference with service or install and maintain, at his expense, the
          corrective measures necessary to reasonably limit the interference
          with service. If the customer fails to take corrective measures in a
          timely manner and continues to use the load causing the interference
          with service, the Utility may terminate service after prior notice in
          accordance with Rule No. 6 of these Rules and Regulations. Customer
          shall contact the local Utility office for maximum allowable motor
          starting currents.

     5.   Power Factor Correction

          The customer shall provide, at his expense, the necessary power factor
          corrective equipment to maintain a power factor of at least 90%
          lagging unless a power factor adjustment is being applied for billing
          purposes in accordance with appropriate rate schedules.

                                   (Continued)

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

Issued: 9/21/84
                                    Issued By:
Effective: 9/21/84                Joe L. Gremban
                                     President
Advice No.: 231-E

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

                                                              EXHIBIT K - 1 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              3rd Revised   P.S.C.N. Sheet No. 47
Tariff No. Electric No. 1         Cancelling 2nd Revised   P.S.C.N. Sheet No. 47

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)

A.   Applicability

     Under provisions of this rule, the utility will purchase energy or energy
and capacity from qualifying cogenerators and small power production facilities.
These facilities will be allowed to operate in parallel with the utility.

     1.   A Qualifying facility is one that meets the criteria set forth in
          Subpart B, Sections 292.201 - 292.207 of the FERC rules. (45 Fed. Reg.
          17959)

     2.   Parallel generation is defined as a system in which the QF's
          generation can be connected to a bus common with the utility's system.
          Power transfer between the QF's facilities and the utility's system is
          a common result.

B.   BUY-SELL ARRANGEMENT

     1.   Utility will purchase power from qualifying small power production or
          cogeneration facilties at a rate which reflects the cost which
          Utility can avoid as a result of obtaining the power.

     2.   Utility will sell power to qualifying small power production or
          cogeneration facilities based on filed Rate Schedules applicable to
          comparable customers without generation.

     3.   Utility offers two metering options to QF's.

          a.   Netting Generation and Load - Metering Option I

               1.   The QF can choose to have the metering arranged so that
                    Utility purchases the

                                   (Continued)

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

Issued: 3/20/81
                                    Issued By:
Effective: 3/20/81                Joe L. Gremban
                                     President
Advice No.: 176-E

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

                                                              EXHIBIT K - 2 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada              4th Revised   P.S.C.N. Sheet No. 48
Tariff No. Electric No.           Cancelling 3rd Revised   P.S.C.N. Sheet No. 48

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

          a.   Netting Generation and Load - Metering Option I (continued)

               1.   (Continued)
                    net energy which the QF does not use, and so that Utility
                    sells the net energy which the QF does not generate.

               2.   When the QF's generation output is greater than his load,
                    Utility will purchase the excess energy which the QF does
                    not use. The purchase meters will register only the energy
                    which is supplied from the QF's system to Utility's system.

               3.   When the QF's generation output is less than his load,
                    Utility will charge the QF only for the power requirements
                    which are not supplied by the QF's generation. The billing
                    meters will register only the power requirements which are
                    supplied from Utility's system to the QF's system.

               4.   Neither the purchase meters nor the billing meters will be
                    allowed to reverse rotation.

               5.   If the applicable rate schedule requires demand metering the
                    demand meter will register only the demand which is supplied
                    from Utility's system to the QF's system. This demand meter
                    will be used to determine the billing demand and the
                    applicable rate schedule.

                                   (Continued)

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

Issued: 5/4/81

                                   Issued By:
Effective: 5/4/81                Joe L. Gremban
                                    President

Advice No.: 178-E

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

                                   Appendix C
                                  Page 2 of 7

                                                              EXHIBIT K - 3 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada            3rd Revised   P.S.C.N. Sheet No. 48 A
Tariff No. Electric No.         Cancelling 2nd Revised   P.S.C.N. Sheet No. 48 A

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

          a.   Netting Generation and Load - Metering Option I (continued)

               5.   (Continued)
                    It is feasible that the QF's generation could reduce his
                    demand enough to move the customer to a different rate
                    schedule.

          b.   Separate Generation and Load - Metering Option II

               1.   The Qualifying Facility can choose to have the metering
                    arranged so that Utility purchases 100% of the QF's
                    generation output, and so that Utility sells 100% of the
                    QF's load requirements.

               2.   The QF's generation and load shall be treated separately and
                    independently. For example, if a cogeneration facility
                    produces 50 KW and consumes 30 KW, it would be treated the
                    same as another qualifying facility that produces 50 KW, and
                    is located next to a factory that uses 30 KW.

               3.   The QF should note that the purchase meter will reverse its
                    rotation if the generator loses power and goes into a
                    motoring state. The Utility may require a reverse power
                    relay to prevent this condition.

C.   INTERCONNECTION COSTS

     1.   The Qualifying Facility shall pay all costs of interconnection with
          the Utility's facilities.

                                   (Continued)

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

Issued: 5/4/81

                                   Issued By:
Effective: 5/4/81                Joe L. Gremban
                                    President

Advice No.: 178-E

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

                                   Appendix C
                                  Page 3 of 7

                                                              EXHIBIT K - 4 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada            2nd Revised   P.S.C.N. Sheet No. 48 B
Tariff No. Electric No.         Cancelling 1st Revised   P.S.C.N. Sheet No. 48 B

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

C.   Interconnection Costs - (Continued)

     2.   Utility financing for specified portions of interconnection costs is
          available on an individual contract basis. The contracts will be
          negotiated with each Qualifying Facility and will include, but not be
          limited to, the following terms:

          a.   The Utility will finance only the service drop and metering
               equipment.

          b.   The owner of the Qualifying Facility will be required to execute
               a promissory note in an amount equal to the actual costs of
               construction, bearing interest at the prime rate prevailing at
               the time of execution plus 1%.

          c.   The Utility will require that the debt be secured by property,
               bond, letter of credit, or other adequate security.

          d.   Monthly payment amounts and repayment schedules will be
               determined on a case-by-case basis.

D.   QF DESIGN & OPERATING REQUIREMENTS

     The QF must meet Utility's latest design and operating specifications in
     addition to all national, state, and local construction and safety codes.

     Utility's design and operating specifications are the minimum requirements
     that the QF must meet.

                                   (Continued)

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

Issued: 10/21/81

                                    Issued By:
Effective: 10/21/81               Joe L. Gremban
                                    President

Advice No.: 189-E

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

                                   Appendix C
                                   Page 4 of 7

                                                              EXHIBIT K - 5 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada             1st Revised  P.S.C.N. Sheet No. 48 C
Tariff No. Electric No. __       Cancelling Original     P.S.C.N. Sheet No. 48 C

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

D.   QF DESIGN & OPERATING REQUIREMENTS (Continued)

     These requirements are intended to protect other customers and Utility from
     damage caused by the parallel generation facility.

     These design requirements are not intended to protect the QF's generation
     facility from every possible source of damage. The parallel generation QF
     may wish to install additional protective equipment to protect his
     generation facility.

     1.   All protective device relay settings and all electrical schematics
          must be approved in writing by Utility.

     2.   The QF will purchase, own, operate, and maintain the required
          protective equipment.

     3.   Utility reserves the right to require additional protective equipment
          and safety measures as further experience may dictate.

     4.   The operation of the QF's generation facility must not reduce the
          quality of service to other Utility customers. No abnormal voltages,
          currents, frequencies, or interruptions are permitted.

     5.   The QF will at no time energize a de-energized Utility circuit,
          without the permission and the supervision of Utility personnel.

     6.   The QF shall not bypass any of the protective relays or equipment.

                                   (Continued)

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

Issued:    5/4/81
                                   Issued By:
Effective: 5/4/81                Joe L. Gremban
                                    President
Advice No.: 178-E

                                                              EXHIBIT K - 6 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada             1st Revised  P.S.C.N. Sheet No. 48 D
Tariff No. Electric No. __       Cancelling Original     P.S.C.N. Sheet No. 48 D

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

D.   QF DESIGN & OPERATING REQUIREMENTS (Continued)

     7.   The QF is responsible for damage caused to other customers and to
          Utility as a result of mis-operation or malfunction of the QF's
          generation facility or protective equipment.

     8.   Utility is not responsible for damage caused to the QF's facility as a
          result of acts over which Utility has no control.

     9.   Utility is not responsible for damage caused to the QF's facility as a
          result of automatic or manual reclosing.

     10.  The QF is responsible for performing scheduled maintenance on the
          generation facility and the protective equipment to keep the facility
          in proper operating condition. Utility reserves the right to inspect
          the customer's facility to check for a hazardous condition or a lack
          of scheduled maintenance.

     11.  Utility reserves the right to discontinue parallel generation with
          reasonable prior notice for any of the following reasons:

          a.   Utility needs to perform non-emergency maintenance or repair of
               utility facilities.

          b.   The QF's generation reduces the quality of service to other
               customers.

          c.   Inspection of the QF's facility reveals a hazardous condition or
               a lack of scheduled maintenance.

                                   (Continued)

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

Issued:    5/4/81
                                   Issued By:
Effective: 5/4/81                Joe L. Gremban
                                    President
Advice No.: 178-E

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

                                   Appendix C
                                  Page 6 of 7

                                                              EXHIBIT K - 7 of 7

SIERRA PACIFIC POWER COMPANY
100 E. Moana Lane, Reno, Nevada             Original     P.S.C.N. Sheet No. 48 E
Tariff No. Electric No. __       Cancelling ________     P.S.C.N. Sheet No. ____

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

                                   Rule No. 15

                  COGENERATORS AND SMALL POWER PRODUCERS (QF'S)
                                   (Continued)

D.   QF DESIGN & OPERATING REQUIREMENTS (Continued)

     12.  Utility reserves the right to open the main disconnecting device and
          cease parallel generation without prior notice in the event of a
          system emergency.

          a.   The QF is advised that his generation facility must be capable of
               withstanding load rejection of this nature. Utility is not
               responsible for any damage caused to the QF's equipment as a
               result of disconnection from Utility's system.

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

Issued: 5/4/81
                                   Issued By:
Effective: 5/4/81                Joe L. Gremban
                                    President
Advice No.: 178-E

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

                                   Appendix C
                                  Page 7 of 7

                                                           EXHIBIT L (1) 1 of 13

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

                    SMALL POWER PRODUCTION AND CO-GENERATION

                                TABLE OF CONTENTS

      Section                                                           Page No.
      -------                                                           --------
1.0   INTRODUCTION...................................................       1
2.0   BACKGROUND - DEFINITIONS.......................................       2
3.0   POLICY STATEMENT...............................................       3
4.0   METERING ARRANGEMENT...........................................       3
5.0   CUSTOMER DESIGN REQUIREMENTS...................................       5
6.0   CUSTOMER DESIGN RECOMMENDATIONS................................       8
7.0   INDUCTION & SYNCHRONOUS GENERATION DIAGRAMS....................
8.0   CUSTOMER OPERATING REQUIREMENTS................................      11

1.0  INTRODUCTION

     1.1  This document presents Sierra Pacific Power Company's (SPPCo's) policy
          and metering arrangement for the parallel operation of small power
          production and co-generation facilities. In addition, this document
          provides the customer design and operating requirements to be applied
          to a customer owned generation facility of less than 1000 KVA
          generating parallel to SPPCo's system.

     1.2  The Customer Design Requirements and the Customer Operating
          Requirements outline the design specifications, the protective
          equipment, and the operating procedures necessary on the customer's
          part to ensure safe, effective operation of the parallel customer
          generation facility.

[SEAL of S.T.R.C. APPROVED]

----------------------------------------------------------------------------------------------------
CHG   DATE                  DESCRIPTION                   DWN  DSGN  CHKD  APVD
--------------------------------------------------------------------------------

                                                                                     SHEET 1 OF 13
----------------------------------------------------------------------------------------------------
                                                                                   VOL   SECT   PAGE
----------------------------------------------------------------------------------------------------
                                                                                    1    2.2
----------------------------------------------------------------------------------------------------
 1   2/84         Added 1 3  Generation Above 1MW               GWC
----------------------------------------------------------------------------------------------------
     APPROVED BY                           ENGINEERING & CONSTRUCTION STANDARD
-------------------                                                                -----------------
                                         SMALL POWER PRODUCTION & CO-GENERATION
                                        CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
/s/ Illegible        [SPPCO. LOGO]              FOR PARALLEL GENERATION
-------------------                                                                -----------------
DESIGNED    CHECKED
  GLP                                                                              -----------------
-------------------                          SIERRA PACIFIC POWER CO.                 DRAWING NO.
DRAWN        DATE                                                                      2.2 GN 01
           08/24/81
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 1 of 13

                                                         EXHIBIT L (1) - 2 of 13

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

     1.3  The customer _____ and operating requirements__ units or groups of
          units owned by one individual totaling 1 MW or greater will be
          reviewed on a case-by-case basis. However, individual units greater
          than 1 MW will be required to have governors. Units or groups of
          smaller units in one location with individual or total aggregate
          capacity greater than 1 MW may require installation of supervisory
          control capability. Units greater than 1 MW and connected directly to
          the transmission system must use synchronous generators with high
          speed excitation controls. Large units connected to the distribution
          system will be reviewed on a case-by-case basis to determine the type
          of generator required.

2.0  BACKGROUND - DEFINITIONS

     2.1  With energy shortages prevailing and gas-oil supplies diminishing, it
          is very important to conserve energy by increasing efficiency, and to
          reduce gas-oil consumption by encouraging the development of
          non-gas-oil types of generation.

     2.2  Small power production and co-generation are two very effective
          methods of conserving energy and reducing gas-oil consumption.

     2.3  Small power production is exotic generation for which the primary
          fuel/energy sources are wind, hydro, solar, biomass, waste, or
          renewable resources. Small power production facilities do not use
          gas-oil fuels as the primary fuel source.

     2.4  Co-generation is the simultaneous production of electricity and useful
          heat in a way that requires less fuel than the separate production of
          electricity and heat. Co-generation facilities sequentially extract
          energy from a thermal process, and produce electricity and useful
          thermal energy. This recovery of waste heat by-products and the
          simultaneous production of two energy products is a more efficient use
          of gas-oil fuels than the separate production of two energy products.

     2.5  The efficiency of small power production and co-generation can be
          maximized, if the customer's generation is connected parallel to the
          utility's system, so that the excess electricity the customer does not
          use is sold to the utility to be used by other customer's.

     2.6  A parallel generation system is designed such that the customer's
          generation can be connected to a bus common with the utility's system.
          Power transfer between the customer's system and the utility's system
          is a common result.

----------------------------------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                            -----------------
[SPPCO. LOGO]     SMALL POWER PRODUCTION & CO-GENERATION     1    2.2
                 CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
                      FOR PARALLEL GENERATION                                   SHEET 2 OF 13
                                                            -----------------   -------------
                      SIERRA PACIFIC POWER CO.
                                                            -----------------    DRAWING NO.
                                                                                   2.2 GN 01
                                                            -----------------

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

                                   Appendix G
                                  Page 2 of 13

                                                         EXHIBIT L (1) - 3 of 13

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

3.0  POLICY STATEMENT

     3.1  It is SPPCo's policy to encourage the development of small power
          production and co-generation facilities with the intent of reducing
          gas-oil consumption and increasing efficiency.

     3.2  SPPCo allows "qualifying" small power production and co-generation
          facilities to generate parallel to the utility's system, so that the
          customer can reduce his power required from SPPCo, and so that the
          customer can sell his energy to SPPCo.

     3.3  The parallel generation must be safely integrated into SPPCo's system
          without degrading the integrity of the existing system, and without
          economically burdening the existing customers.

     3.4  Safety is the primary concern with parallel customer generation
          because of the distinct possibility of back-feed into the distribution
          system that previously was immune to back-feed safety hazards.

     3.5  SPPCo requires the parallel generation customer to install certain
          protective devices, and requires the customer to operate his facility
          in a manner that will prevent injury to customers and SPPCo personnel,
          and will prevent damage to customer and SPPCo equipment.

     3.6  SPPCo requires the parallel generation customer to assume the
          responsibilities described in this document.

4.0  METERING ARRANGEMENT

     4.1  SPPCo will purchase electricity from qualifying small power production
          or co-generation facilities at a rate that reflects the cost SPPCo can
          avoid as a result of obtaining the electricity.

     4.2  SPPCo will sell electricity to qualifying small power production or
          co-generation facilities based on filed Rate Schedules applicable to
          comparable customers without generation.

     4.3  SPPCo offers two metering options:

          4.3.1 Netting Generation and Load - Metering Option I

               4.3.1.1 The customer can choose to have the metering arranged so
                    that: SPPCo purchases the net energy from the customer's
                    generator that the customer does not use; and SPPCo sells,
                    to the customer, the net energy that the customer uses but
                    does not generate.

----------------------------------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                            -----------------
[SPPCO. LOGO]     SMALL POWER PRODUCTION & CO-GENERATION     1    2.2
                 CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
                      FOR PARALLEL GENERATION                                   SHEET 3 OF 13
                                                            -----------------   -------------
                      SIERRA PACIFIC POWER CO.
                                                            -----------------    DRAWING NO.
                                                                                   2.2 GN 01
                                                            -----------------

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

                                   Appendix G
                                  Page 3 of 13

                                                         EXHIBIT L (1) - 4 of 13

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

                4.3.1.2 When the customer's generation output is greater than
                        his load, SPPCo will purchase the excess energy that the
                        customer does not use. The purchase meters will register
                        only the energy supplied from the customer's system to
                        SPPCo's system.

                4.3.1.3 When the customer's generation output is less than his
                        load, SPPCo will charge the customer only for the power
                        requirements that are supplied by SPPCo. The billing
                        meters will register only the power requirements
                        supplied from SPPCo's system to the customer's system.

                4.3.1.4 Both the purchase meters and the billing meters will be
                        uni-directional or not allowed to reverse rotation.

                4.3.1.5 If the applicable rate schedule requires demand
                        metering, the demand meter will register only the demand
                        supplied from SPPCo's system to the customer's system.
                        This demand meter will be used to determine the billing
                        demand and the applicable rate schedule.

                        It is possible that the customer's generation could
                        reduce his demand enough to move the customer to a
                        different rate schedule.

          4.3.2 Separate Generation and Load - Metering Option II

                4.3.2.1 The customer can choose to have the metering arranged so
                        that SPPCo purchases 100% of the customer's generation
                        output, and so that SPPCo sells, to the customer, 100%
                        of his load requirements.

                4.3.2.2 The customer's generation and load shall be treated
                        separately and independently. For example, if a
                        co-generation facility produces 50 KW and consumes 30
                        KW, it would be treated the same as another qualifying
                        facility that produces 50 KW, and is located next to a
                        shop that uses 30 KW.

                4.3.2.3 The customer is not allowed to connect load on the
                        generator side of the purchase meter, other than the
                        minimal load associated with the generator.

----------------------------------------------------------------------------------------------------
[SPPCO. LOGO]     ENGINEERING & CONSTRUCTION STANDARD      VOL   SECT   PAGE
                                                           -----------------
                 SMALL POWER PRODUCTION & CO-GENERATION     1     2.2
                CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------   SHEET 4 OF l3
                         FOR PARALLEL GENERATION                               -------------
                        SIERRA PACIFIC POWER CO.           -----------------    DRAWING NO.
                                                                                 2.2 GN 01
                                                           -----------------
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 4 of 13

                                                         EXHIBIT L (1) - 5 of 13

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

                        The customer should note that the purchase meter will be
                        bi-directional. The purchase meter will reverse its
                        rotation if the customer's generator loses power and
                        goes into a motoring state or in any way places a load
                        on the line. SPPCo may require a reverse power relay
                        to prevent bi-directional powerflow or may require
                        additional metering.

5.0  CUSTOMER DESIGN REQUIREMENTS

     This section provides the minimum design specifications that the customer's
     generation facility must meet, and specifies the minimum protective
     equipment that the customer's generation facility must have installed.

     The design specifications and protective equipment listed are intended to
     protect other customers and SPPCo from damage that could be caused by the
     parallel generation facility.

     These requirements are not intended to protect the customer's generation
     facility from every possible source of damage. The parallel generation
     customer may wish to install additional protective equipment to protect his
     generation facility.

     5.1  Applicable Codes - The customer's installation must meet all
          applicable national, state, and local construction and safety codes.

     5.2  Relay Settings - Electrical Schematics Approval - All protective
          device relay settings and all electrical schematics must be approved
          in writing by SPPCo.

     5.3  Customer Responsibilities - The customer will purchase, own, operate,
          and maintain the required protective equipment.

     5.4  Additional Protective Equipment - SPPCo reserves the right to require
          additional protective equipment and safety measures as further
          experience may dictate.

     5.5  Synchronous and Induction Generation - Capacity less than 100 KVA

          5.5.1 Full Load Rejection - The customer's generation facility must be
                designed with the capability or protection to withstand sudden
                loss of load.

          5.5.2 De-energized SPPCo Circuit - Electrical relays must be provided
                to prevent the customer's generator from being connected
                parallel to SPPCo's system if SPPCo's system is de-energized.

----------------------------------------------------------------------------------------------------
[SPPCO. LOGO]     ENGINEERING & CONSTRUCTION STANDARD      VOL   SECT   PAGE
                                                           -----------------
                 SMALL POWER PRODUCTION & CO-GENERATION     1     2.2
                CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------   SHEET 5 OF l3
                         FOR PARALLEL GENERATION                               -------------
                        SIERRA PACIFIC POWER CO.           -----------------    DRAWING NO.
                                                                                 2.2 GN 01
                                                           -----------------
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 5 of 13

                                                         EXHIBIT L (1) - 6 of 13

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

          5.5.3 Generator Circuit Breaker - The generator must have a generator
                circuit breaker capable of interrupting the maximum anticipated
                fault current and isolating the customer's generation from
                SPPCo's system. The generator circuit breaker must be equipped
                with thermal-magnetic overcurrent or equivalent devices on each
                phase.

                The generator circuit breaker must be grouped with the main
                service disconnects, readily accessible, and nearest the point
                of entrance of the service-entrance conductors as specified in
                the NEC 230-72.

                The generator circuit breaker or enclosure must be capable of
                being locked and/or sealed by SPPCo personnel to physically
                prevent closing the circuit breaker when SPPCo personnel are
                working on the line.

          5.5.4 Voltage Sensing Location - The voltage sensing location for the
                protective relays must be on the SPPCo side of any customer
                operated disconnect (see sheets 8-9).

          5.5.5 Overcurrent Protection - Phase overcurrent protection is
                required to protect the generator from fault current and
                overload current. Ground overcurrent protection is required, if
                applicable.

          5.5.6 Over/Under Voltage Protection - Overvoltage and under-voltage
                protection is required. Time delay is recommended on the voltage
                relays.

          5.5.7 Underfrequency Protection - Underfrequency protection without
                time delay is required. Overfrequency protection may be
                required.

          5.5.8 Loss-of-Phase Protection - Negative sequence current or
                loss-of-phase protection is required on three phase generators.
                The customer is responsible for protecting his generator, from
                negative sequence currents that could overload and severely
                damage the customer's generator. Negative sequence currents will
                occur during single phasing conditions on SPPCo's system.

          5.5.9 Sychronizing Equipment - Synchronous generators require
                synchronizing equipment to be provided at the main, generator,
                and other breakers as necessary. The generator must be
                brought on-line parallel to SPPCo's system by one of the
                following methods:

                5.5.9.1 Automatic synchronizing.

----------------------------------------------------------------------------------------------------
[SPPCO. LOGO]     ENGINEERING & CONSTRUCTION STANDARD      VOL   SECT   PAGE
                                                           -----------------
                 SMALL POWER PRODUCTION & CO-GENERATION     1     2.2
                CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------   SHEET 6 OF l3
                         FOR PARALLEL GENERATION                               -------------
                        SIERRA PACIFIC POWER CO.           -----------------    DRAWING NO.
                                                                                 2.2 GN 01
                                                           -----------------
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 6 of 13

                                                         EXHIBIT L (1) - 7 of 13

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

               5.5.9.2 Manual synchronizing - note that a synchronizing check
                    relay is also required with manual synchronizing to protect
                    the customer's generator from excessive transient torques
                    that could damage the customer's equipment.

               5.5.9.3 Induction starting - provided that the inrush current
                    does not cause voltage flickers on SPPCo's system greater
                    than 4%.

          5.5.10 Voltage Regulation Equipment - Synchronous generators require
               voltage regulation equipment to maintain the Customer's service
               voltage within 5% above or below nominal service voltage (i.e.
               120 volts +/- 6 volts). Customers in California are required to
               maintain their service voltage in accordance with the
               Conservation Voltage Reduction Program (e.g. 114 volts to 120
               volts).

          5.5.11 Primary Voltage Changes - The generator exciter system and
               voltage regulation equipment on synchronous generators must be
               capable of operating subject to normal primary voltage changes on
               SPPCo's system ranging from 5% above or below nominal primary
               voltage (e.g. 24.9 KV +/- 5%).

     5.6  Synchronous and Induction Generation: Capacity 100 KVA - 1000 KVA

          The requirements described in section 5.0 also apply to 100 KVA to
          1000 KVA generation.

          5.6.1 Overfrequency Protection - Overfrequency in addition to
               underfrequency protection is required. Frequency protection shall
               not have time delay.

          5.6.2 Power Factor Correction - Power factor correction could be
               required at SPPCo's option on induction generators greater than
               100 KVA.

     5.7  D.C. Generation With Inverter

          5.7.1 All requirements listed for synchronous generators shall apply
               to d.c. generator/inverter combinations with the following
               exceptions:

               5.7.1.1 The power factor shall be within the range of 0.9 lagging
                    to 0.9 leading over the full range of power output.

               5.7.1.2 The synchronizing check relay is not required on line
                    commutated inverters that derive their wave-form and
                    frequency from SPPCo's signal.

----------------------------------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                            -----------------
[SPPCO. LOGO]     SMALL POWER PRODUCTION & CO-GENERATION     1    2.2
                 CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
                          FOR PARALLEL GENERATION                               SHEET 7 OF 13
                                                            -----------------   -------------
                          SIERRA PACIFIC POWER CO.
                                                            -----------------    DRAWING NO.
                                                                                  2.2 GN 01
                                                            -----------------

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

                                   Appendix G
                                  Page 7 of 13

                                                         EXHIBIT L (1) - 8 of 13

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

               5.7.1.3 See section H-6.0 for harmonic voltage and current
                    operating requirements.

6.0  CUSTOMER DESIGN RECOMMENDATIONS

     This section provides recommended protection that the customer should
     consider adding to the generation facility. Aqain, the previous minimum
     design requirements are not intended to protect the customer's generation
     facility from every possible source of damage.

     Additional equipment beyond the minimum required and recommended protection
     may be desired to fully protect the customer's generation facility.

     6.1  Over/Under-Speed Protection - Overspeed and underspeed protection are
          recommended.

     6.2  Reverse Power Protection - Anti-motoring or reverse power protection
          is recommended. A lack of sufficient power at the prime mover will
          cause the customer's generator to motor instead of generate. This
          condition can be very costly to the customer.

     6.3  Impedance Neutral Grounding - Impedance neutral grounding is
          recommended.

     6.4  Voltage Surge Protection - Voltage surge protection is recommended.

     6.5  Generator Differential Protection - Generator differential protection
          is recommended.

     6.6  Loss of Excitation Protection - Loss of excitation protection is
          recommended.

     6.7  Unity Power Factor - It is recommended that synchronous generators be
          set to hold near-unity power factor.

     6.8  Relay Targets - Targets or devices that indicate the operation and
          status of a relay are recommended. Targets are very important to
          troubleshooting the generation facility.

7.0  INDUCTION AND SYNCHRONOUS GENERATION DIAGRAMS

     Typical one-line diagrams illustrating the required equipment for both
     synchronous and induction generators follow. Variations to these designs
     are acceptable provided the intent of this section is met, and provided the
     design is reviewed and approved in writing by SPPCo.

----------------------------------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                            -----------------
[SPPCO. LOGO]     SMALL POWER PRODUCTION & CO-GENERATION     1    2.2
                 CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
                         FOR PARALLEL GENERATION                                SHEET 8 OF 13
                                                            -----------------   -------------
                         SIERRA PACIFIC POWER CO.
                                                            -----------------    DRAWING NO.
                                                                                  2.2 GN 01
                                                            -----------------

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

                                                         EXHIBIT L (1) - 9 of 13

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

              INDULTION GENERATION LESS THAN kVA - ONE LINE DIAGRAM
              -----------------------------------------------------

[GRAPHIC]

(27) Undervoltage
(50) Instantaneous phase overcurrent
(51) Time phase overcurrent
(50N) Instantaneous neutral overcurrent
(51N) Time neutral overcurrent
(59) Overvoltage
(81) Underfrequency/overfrequency*
(86) Lockout relay

CUSTOMER REQUIREMENTS
A) Full load rejection
B) Generator circuit breaker**
C) Prevention from energizing a de-energized SPPCo. circuit
D) Phase overcurrent protection: fault current and overload current
E) Ground overcurrent protection (if applicable)
F) Overvoltage and undervoltage protection
G) Underfrequency protection
H) Overfrequency protection*
I) Power factor correction on generators greater than 100 kVA at SPPCo.'s option
J) Negative sequence current protection

SPPCo. REQUIREMENTS
A) Dedicated distribution transformer
B) SPPCo disconnect switch

RECOMMENDED PROTECTION
A) Impedance neutral grounding
B) Voltage surge protection
C) Anti-motoring protection
D) Generator differential protection*
E) Overspeed and underspeed protection

*    Generators 100 kVA - 1000 kVA only

**   Must be grouped with main disconnects, readily accessible, and nearest
     point of entrance of service-entrance conductors. NEC 230-72. Must be
     capable of being locked and/or sealed by SPPCo personnel.

***  Voltage sensing location must be on SPPCo side of any customer disconnect.

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

                                                  APPRV'D BY                   ENGINEERING STANDARD              SHT. 9 OF 13
---------------------------------------------        STRC                                                        ------------------
                                                 /s/ Illegible       CUSTOMER DESIGN AND OPERATING REQUIREMENTS  CHANGE 1
--------------------------------------------------------------------          FOR PARALLEL GENERATION            ------------------
                                                DRAWN BY                                                         DRAWING NO.
---------------------------------------------                                                                    2.2 GN 01
                                                J. OWNES
--------------------------------------------------------------------
1     ADDED PAR 1.3   2/84   ___   __________   ENGINEER
---------------------------------------------
CH_   DESCRIPTION     DATE   ENG   APPRV'D      G. PORTER            RENO SIERRA PACIFIC POWER CO. NEVADA
-----------------------------------------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 9 of 13

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

                                                        EXHIBIT L (1) - 10 OF 13

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

                   SYNCHRONOUS GENERATION LESS THAN 1000 kVA
                                ONE LINE DIAGRAM

                                    [GRAPHIC]

                                                         [SEAL OF] STRC APPROVED

(25)  Synchronizing, synchrocheck, deadline
(27)  Undervoltage
(50)  Instantaneous phase overcurrent
(51)  Time phase overcurrent
(50N) Instantaneous neutral overcurrent
(51N) Time neutral overcurrent
(59)  Overvoltage
(81)  Underfrequency/overfrequency*
(86)  Lockout relay

CUSTOMER REQUIREMENTS

A)   Full load rejection
B)   Generator circuit breaker**
C)   Prevention from energizing a de-energized SPPCo. circuit
D)   Phase overcurrent protection: fault current and overload current
E)   Ground overcurrent protection (if applicable)
F)   Overvoltage and undervoltage protection
G)   Underfrequency protection
H)   Overfrequency protection*
I)   Synchronizing equipment, synchrocheck relay required with manual
     synchronizing
J)   Voltage regulation
K)   Negative sequence current protection

SPPCo. REQUIREMENTS

A)   Dedicated distribution transformer
B)   SPPCo disconnect switch

RECOMMENDED PROTECTION

A)   Impedance neutral grounding
B)   Voltage surge protection
C)   Anti-motoring protection
D)   Generator differential protection*
E)   Loss of excitation protection*
F)   Overspeed and underspeed protection

*    Generators 100 kVA - 1000 kVA only

**   Must be grouped with main disconnects, readily accessible, and nearest
     point of entrance of service-entrance conductors. NEC 230-72. Must be
     capable of being locked and/or sealed by SPPCo personnel.

***  Voltage sensing location must be on SPPCo side of any customer disconnect.

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

                                                    APPRV'D BY                ENGINEERING STANDARD              SHT. 10 OF 13
-----------------------------------------------        STRC                                                     -------------
                                                    ILLEGIBLE      CUSTOMER DESIGN AND OPERATING REQUIREMENTS   CHANGE 1
-------------------------------------------------------------------          FOR PARALLEL GENERATION            -------------
                                                     DRAWN BY                                                    DRAWING NO.
-----------------------------------------------                                                                  2.2 GN 01
                                                      J.OWNES
-------------------------------------------------------------------
1     ADDED PAR 1.3   2/84   ___   ILLEGIBLE         ENGINEER
-----------------------------------------------
CHG   DESCRIPTION     DATE   ENG    APPRV'D          G. PORTER     RENO SIERRA PACIFIC POWER CO. NEVADA
-----------------------------------------------------------------------------------------------------------------------------

                                   Appendix G
                                  Page 10 of 13

                                                        EXHIBIT L (1) - 11 of 13

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

     8.0  CUSTOMER OPERATING REQUIREMENTS

          This section provides the operating requirements that the customer
          must follow, and the responsibilities that the customer must assume
          for operating his generation parallel to SPPCo's system.

          8.1  Quality of Service - The operation of the customer's generation
               facility must not reduce the quality of service to other SPPCo
               customers. No abnormal voltages, currents, frequencies, or
               interruptions are permitted.

          8.2  De-energized SPPCo Circuit - The customer will at no time
               energize a de-energized SPPCo circuit, without the permission and
               the supervision of SPPCo personnel.

          8.3  Bypassing Relays - The customer shall not bypass any of the
               protective relays or equipment.

          8.4  Inhibited Parallel Operation - If while operating parallel to
               SPPCo's system, or while attempting to bring the generating
               system on-line and operate parallel to SPPCo's system, any of the
               protective relays or devices operate inhibiting parallel
               operation, the customer will follow these procedures prior to
               attempting parallel operation with SPPCo again:

               8.4.1 Determine if SPPCo's circuit is energized or de-energized
                    by checking the status of the relays described in Section
                    E-5.2 and/or contacting the local SPPCo office.

               8.4.2 If it is determined that the SPPCo circuit is and has been
                    continuously energized, then the customer will not attempt
                    to reconnect his system parallel to SPPCo's system, until
                    the cause of protective device operation has been corrected,
                    and it has been determined that the customer's system is in
                    proper operating condition.

               8.4.3 If it is determined that the SPPCo circuit is de-energized,
                    the customer must not attempt to reconnect his system and
                    operate parallel with SPPCo's system until he has confirmed
                    that power has been restored and SPPCo's circuit is
                    energized.

               8.4.4 The customer is not prohibited from isolating his system
                    and supplying his own load while SPPCo's circuit is
                    de-energized.

----------------------------------------------------------------------------------------------------
[SPPCo. LOGO]      ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                           -----------------
                 SMALL POWER PRODUCTION & CO-GENERATION     1     2.2
                                                           -----------------
                CUSTOMER DESIGN & OPERATING REQUIREMENTS                       SHEET 11 OF 13
                         FOR PARALLEL GENERATION           -----------------   --------------
                        SIERRA PACIFIC POWER CO.
                                                           -----------------     DRAWING NO.
                                                                                   2.2 GN 01
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                 Page 11 of 13

                                                        EXHIBIT L (1) - 12 of 13

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

               NOTE The designs and equipment outlined in this document do not
               provide for the customer to isolate his system and supply his own
               load while SPPCo's circuit is de-energized. If the customer
               wishes to do this, he must install additional protective
               equipment subject to a more complex and stringent design. These
               cases will be studied on an individual basis.

     8.5  Automatic Reclosing - The customer is not allowed to automatically
          reclose parallel to SPPCo's system if any of the protective devices
          operate.

          However, if the customer ceases parallel operation with SPPCo because
          of an anti-motoring operation or lack of applicable power source
          (wind, water, etc.), the customer is allowed to automatically reclose
          parallel to SPPCo system when the energy source resumes to sufficient
          amounts.

          The distinctions between disallowing or allowing automatic reclosing
          are:

          8.5.1 Automatic reclosing is disallowed if parallel operation has been
                ceased due to an abnormal or dangerous condition (fault current,
                overloads, over or under voltage, over or under frequency).

          8.5.2 Automatic reclosing is allowed if parallel operation has been
                ceased due to a lack of sufficient power to the prime mover
                (lack of wind, water, etc.).

     8.6  Harmonics - The customer's generation facility shall not cause
          excessive distortion of the sinusoidal voltage wave. The maximum
          allowable total root-mean-square (RMS) harmonic current is 5% of the
          fundamental 60 Hz RMS current. The maximum allowable total RMS
          harmonic voltage (all harmonics) is 2% of the nominal AC voltage. In
          addition, the RMS voltage of any single voltage harmonic shall not
          exceed 1%.

     8.7  Damage to Other Customers - The customer is responsible for damage
          caused to other customers and to SPPCo as a result of misoperating or
          malfunction of his generation facility or protective equipment.

     8.8  Damage to Generation Customer - SPPCo is not responsible for damage
          caused to the customer's facility as a result of acts over which SPPCo
          has no control.

     8.9  SPPCo Automatic Reclosing - SPPCo is not responsible for damage caused
          to the customer's facility as a result of SPPCo automatic or manual
          reclosing.

----------------------------------------------------------------------------------------------------
[SPPCo. LOGO]                                              VOL   SECT   PAGE
                   ENGINEERING & CONSTRUCTION STANDARD     -----------------
                                                            1     2.2
                 SMALL POWER PRODUCTION & CO-GENERATION    -----------------
                CUSTOMER DESIGN & OPERATING REQUIREMENTS                       SHEET 12 OF 13
                         FOR PARALLEL GENERATION           -----------------   --------------
                        SIERRA PACIFIC POWER CO.
                                                                                 DRAWING NO.
                                                                                  2.2 GN 01
----------------------------------------------------------------------------------------------------

                                   Appendix G
                                 Page 12 of 13

                                                        EXHIBIT L (1) - 13 of 13

--------------------------------------------------------------------------------
                                  ****WARNING****

          RECLOSING CAN CAUSE LOSS OF SYNCHRONISM BETWEEN THE CUSTOMER'S SYSTEM
          AND SIERRA'S SYSTEM, THAT CAN IN TURN SEVERELY DAMAGE THE CUSTOMER'S
          EQUIPMENT

          8.9.1 If feasible, and at the customer's option and expense,
               communications between the customer's circuit breaker and SPPCo's
               circuit breaker can be provided to reduce the risk of
               out-of-synchronism damage. Other measures for protection can be
               considered and implemented if feasible.

     8.10 Scheduled Maintenance and Testing - The customer is responsible for
          performing scheduled maintenance and testing on the generation
          facility and the protective equipment to keep the facility in proper
          operating condition. SPPCo reserves the right to inspect the
          customer's facility to check for a hazardous condition or a lack of
          scheduled maintenance or testing.

     8.11 Discontinue Parallel Generation With Notice - SPPCo reserves the right
          to discontinue parallel generation with reasonable prior notice for
          any of the following reasons:

          8.11.1 SPPCo will be performing non-emergency maintenance or repair of
               utility facilities.

          8.11.2 The customer's generation reduces the quality of service to
               other customers.

          8.11.3. Inspection of the customer's facility reveals a lack
               of scheduled maintenance or testing.

     8.12 Discontinue Parallel Generation Without Notice - SPPCo reserves the
          right to open the main disconnecting device and cease parallel
          generation without prior notice in the event of a system emergency or
          hazardous condition.

          8.12.1 The customer is advised that his generation facility must be
               capable of withstanding load rejection of this nature. SPPCo is
               not responsible for any damage caused to the customer's equipment
               as a result of disconnection from SPPCo's system.

--------------------------------------------------------------------------------
                   ENGINEERING & CONSTRUCTION STANDARD     VOL   SECT   PAGE
                                                           -----------------
[SPPCO. LOGO]    SMALL POWER PRODUCTION & CO-GENERATION     1    2.2
                CUSTOMER DESIGN & OPERATING REQUIREMENTS   -----------------
                         FOR PARALLEL GENERATION                               SHEET 13 OF 13
                                                           -----------------   --------------
                         SIERRA PACIFIC POWER CO.
                                                           -----------------     DRAWING NO.
                                                                                  2.2 GN 01
                                                           -----------------

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

                                   Appendix G
                                 Page 13 of 13

                                                         EXHIBIT L (2) - 1 of 12

--------------------------------------------------------------------------------
      SMALL POWER PRODUCTION AND COGENERATION PLANNING AND DESIGN CRITERIA

                    FOR GENERATION GREATER THAN ONE MEGAWATT*

                                TABLE OF CONTENTS

      Section                                                           Page No.
      -------                                                           --------
1.0   APPLICATION AND POLICY ........................................       2

2.0   CONTRACT INFORMATION ..........................................       3

3.0   INTERCONNECTION AND TRANSIENT STUDY REQUIREMENTS ..............       4

4.0   METERING ......................................................       6

5.0   DESIGN  REQUIREMENTS  AND   SPECIFICATIONS ....................       7

*    Design criteria for qualifying facilities whose output is less than one
     megawatt are specified in SPPCo. Engineering Standard 2.2 GW 01.

--------------------------------------------------------------------------------------------
CHG  DATE              DESCRIPTION                DWN  DSGN  CHKD  APVD
------------------------------------------------------------------------

                                                                             SHEET 1 of __
--------------------------------------------------------------------------------------------
                                                                           VOL   SECT   PAGE
--------------------------------------------------------------------------------------------
                                                                            1    2.2
--------------------------------------------------------------------------------------------

--------------------------------------------------------------------------------------------
     APPROVED BY                     ENGINEERING & CONSTRUCTION STANDARD
-------------------                        SMALL POWER PRODUCTION          -----------------
/s/ Illegible        [SPPCO. LOGO]    AND CO. GENERATION FOR GENERATION
-------------------                        GREATER THAN ONE MEGAWATT       -----------------
DESIGNED    CHECKED
  T.B.        B.B.                                                         -----------------
-------------------                         SIERRA PACIFIC POWER CO.           DRAWING NO.
DRAWN        DATE
           ________
--------------------------------------------------------------------------------------------

                                   Appendix H
                                     Page 1

                                                         EXHIBIT L (2) - 2 of 12

--------------------------------------------------------------------------------
1.0   APPLICATION AND POLICY

     1.1  Application

          The purpose of this standard is to present the planning and design
          requirements which all customer-owned qualifying power production
          facilities (QF) must meet or exceed prior to parallel operation with
          Sierra Pacific Power Company's (SPPCo.'s) electric system. This
          document applies to all customer-owned qualifying power production
          facilities whose gross aggregate output exceeds one megawatt (1 MW).

          The QF Developer and SPPCo. personnel are to use this document when
          planning installations of QF generation. It is emphasized that these
          requirements are general and may not cover all details in specific
          cases. The QF Developer should review project plans with SPPCo. before
          purchasing or installing equipment.

          The abbreviations QF for customer-owned qualified power production
          facility and SPPCo. for Sierra Pacific Power Company will be used for
          the remainder of this standard.

     1.2  QF Definition

          A qualifying facility is one that meets the criteria set forth in
          Subpart 13, Section 202.201-292.207 of the FERC rules.

     1.3  Policy Statements

          o    Under provisions of SPPCo. Rule No. 15, in Nevada, and Rule No.
               21, in California, submitted to and approved by the appropriate
               regulatory agency SPPCo. will purchase energy or energy and
               capacity from qualifying facilities.

          o    QF generation will be integrated into SPPCo.'s electric system in
               a manner that will not adversely impact the quality of service to
               customers or cause adverse impacts to personnel or existing
               equipment.

          o    The QF will be required to operate in a prudent manner that will
               not result in injury to customers or SPPCo. personnel nor cause
               damage to customer or SPPCo. equipment.

--------------------------------------------------------------------------------
                ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                      -----------------
[SPPCO. LOGO]          SMALL POWER PRODUCTION          1    2.2
                  AND COGENERATION FOR GENERATION     -----------------
                     GREATER THAN ONE MEGAWATT                            SHEET 2 OF __
                                                      -----------------   -------------
                       SIERRA PACIFIC POWER CO.
                                                      -----------------    DRAWING NO.
                                                                             2.2 GN 02
                                                      -----------------

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

                                   Appendix H
                                     Page 2

                                                         EXHIBIT L (2) - 3 of 12

--------------------------------------------------------------------------------
2.0  CONTRACT INFORMATION

     2.1  Initial Contact

          Initial developer contact should be addressed to the Manager of Power
          Contracts Engineering Department at (702) 689-4889. A flow chart
          follows to visually aid the QF Developer in defining coordination
          requirements.

          2.1.1 The QF Developer will be required to submit a written request
               for a power purchase agreement. A description of the project
               (resource or fuel, size of unit(s), net generation, and ultimate
               plant total), the project location (township, range, and
               section), and any other pertinent data should be included.

          2.1.2 From the information provided by the QF Developer, SPPCo. will
               provide an estimate of the cost of an interconnection study, the
               alternatives to be studied, and the approximate interconnection
               cost of each alternative to be studied. SPPCo. will also provide
               a draft power purchase agreement, a data sheet to be completed by
               the QF Developer which supplies project study data, and an
               information request regarding the project.

          2.1.3 Fill out and return "Data Request For Generator Interconnection"
               Form.

---------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                          -----------------
[SPPCO. LOGO]             SMALL POWER PRODUCTION          1     2.2
                      AND COGENERATION FOR GENERATION     -----------------
                         GREATER THAN ONE MEGAWATT                            SHEET 3 OF ___
                                                          -----------------   --------------
                          SIERRA PACIFIC POWER CO.
                                                          -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------

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

                                   Appendix H
                                     Page 3

                                                         EXHIBIT L (2) - 4 of 12

--------------------------------------------------------------------------------
3.0  INTERCONNECTION AND TRANSIENT STUDY REQUIREMENTS

     The interconnection study, which develops requirements and alternatives
     with supporting cost estimates for the required interface facilities, is
     required for all projects. The transient study is required when SPPCo.
     determines that the size and location of the proposed QF may cause
     conditions detrimental to the electric system.

     3.1  Interconnection Study

          The interconnection study examines the steady state effect that the QF
          generation has on SPPCo.'s system. The study is computer based and
          models the QF's generation in SPPCo.'s transmission system.

          The study will determine the optimum interconnection alternative for
          the QF Developer's project and recommend a system that meets SPPCo.'s
          reliability and quality of service standards with the lowest overall
          cost to the QF Developer.

          The following is a list of the information developed in the
          interconnection study for use by the QF and SPPCo.

          o    Analysis of alternatives to determine the least expensive
               connection method that meets SPPCo.'s reliability and quality of
               service standards.

          o    Recommended conductor size for the interconnection line
               determined by using the QF Developer's economic data.

          o    Recommended step-up transformer tap range, settings, and
               winding configuration.

          o    Available fault duty.

          o    Recommended BIL ratings.

          o    Expected maximum and minimum voltages.

          o    Voltage sag and surge for largest motor start and unit drop, and
               define any system modifications to meet SPPCo. sag and surge
               requirements.

          o    Additions to SPPCo.'s electric system required to serve QF
               start-up loads.

          o    Possible source of construction power.

          o    Communications, supervisory control, and telemetering
               requirements.

          o    Metering requirements.

          o    Interconnection protection requirements and/or modifications to
               the existing system.

          o    Transfer trip requirements (if any).

---------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                          -----------------
[SPPCO. LOGO]             SMALL POWER PRODUCTION          1     2.2
                      AND COGENERATION FOR GENERATION     -----------------
                         GREATER THAN ONE MEGAWATT                            SHEET 4 OF ___
                                                          -----------------   --------------
                          SIERRA PACIFIC POWER CO.
                                                          -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------

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

                                   Appendix H
                                     Page 4

                                                         EXHIBIT L (2) - 5 of 12

--------------------------------------------------------------------------------
     o    Frequency and type of utility interruption expected.

     o    System reactive requirements.

     o    System operation considerations.

     o    Special facilities, construction schedule, and equipment lead times.

     o    Average incremental losses.

     o    Potential impacts of QF project on system reliability and quality of
          service to existing QF projects and other customers.

     3.1.1 Attachment 1, Part A is a data sheet detailing the information
          required to perform the interconnection study. The QF Developer shall
          utilize the data sheets to submit the data required for the study.

3.2  Transient Study

     High-speed transients can result in degradation of the quality of service,
     equipment damage, and/or potential safety problems. Transients are not
     reviewed in the interconnection study. The transient study is performed
     using a specifically tailored computer program to determine the nature of
     high-speed transients and to evaluate the corrective actions necessary to
     minimize their effects.

     The necessity for a transient study will be determined after the
     preliminary analysis of the interconnection study. The following relative
     criteria increase the necessity for a transient study.

     o    Strength of the interconnected system.

     o    Location with respect to other customer loads.

     o    Probability of isolation of the QF with other loads.

     o    Size of the QF generator.

     o    Connection of EHV (230 kV and above) system.

     3.2.1 Attachment 1, Part B is a data sheet detailing the information
          required to perform the transient study. The QF Developer shall
          utilize the data sheets to submit the data required for the study.

---------------------------------------------------------------------------
                    ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                          -----------------
[SPPCO. LOGO]             SMALL POWER PRODUCTION          1     2.2
                      AND COGENERATION FOR GENERATION     -----------------
                         GREATER THAN ONE MEGAWATT                            SHEET 5 OF ___
                                                          -----------------   --------------
                          SIERRA PACIFIC POWER CO.
                                                          -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------

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

                                   Appendix H
                                     Page 5

                                                         EXHIBIT L (2) - 6 of 12

--------------------------------------------------------------------------------
4.0  METERING

     4.1  Metering Location

          Metering of capacity and energy purchased from the QF will normally be
          accomplished at the point of delivery. If point-of-delivery metering
          is not practical, metering may be established at other locations.
          Exact location will be determined on a site-specific basis. All
          metering will be compensated to the point of delivery.

     4.2  CT and PT Location

          The QF Developer shall make provisions in their design to include the
          installation of the metering CTs and PTs by SPPCo. The installation
          will be site specific with design approval by SPPCo. The CTs and PTs
          shall be located such that there are no taps prior to their location
          in the circuit when viewed from the SPPCo. system. The CTs and PTs
          will be metering class and will be used for revenue metering only. No
          customer-owned metering and relaying will be allowed in the metering
          circuits.

     4.3  Metering Provisions

          The metering will be confined to a separate enclosure/cubicle that is
          locked and/or sealed by SPPCo. All metering installations shall comply
          with SPPCo.'s metering standard as detailed in SPPCo.'s Standard
          Volume 2.

          SPPCo. will specify, procure, and install, the metering current
          transformers(CTs), potential transformers(PTs), and meter(s).

---------------------------------------------------------------------------
                   ENGINEERING & CONSTRUCTION STANDARD    VOL   SECT   PAGE
                                                          -----------------
                                                          1     2.2
[SPPCO. LOGO]             SMALL POWER PRODUCTION          -----------------
                     AND COGENERATION FOR GENERATION                          SHEET 6 OF ___
                         GREATER THAN ONE MEGAWATT        -----------------   --------------

                         SIERRA PACIFIC POWER CO.         -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------
--------------------------------------------------------------------------------

                                   Appendix H
                                     Page 6

                                                         EXHIBIT L (2) - 7 of 12

--------------------------------------------------------------------------------
5.0  DESIGN REQUIREMENTS AND SPECIFICATIONS

     5.1  Interconnection Facility

          SPPCo. will design, procure, and construct at the QF Developer's
          expense an interconnection facility (Point of Delivery), separate from
          the QF, that will isolate the generation from SPPCo.'s system when
          required.

          This facility is not intended to protect the QF Developer's
          generation. SPPCo. recommends consulting the generator manufacturer
          and/or engaging the services of a registered electrical engineer for
          the design of the generator unit protection schemes. Generator unit
          protection is the sole responsibility of the QF Developer.

          Location, ownership, control, and maintenance will be defined in the
          Power Purchase and Facilities contracts.

          5.1.1 Facility Components

               The interconnection facility, as a minimum, will consist of a
               control building, the interrupting and isolating device(s),
               protective control devices, and data-acquisition equipment. All
               the above will be enclosed in a fenced yard with restricted
               access. SPPCo. Standard GI0005T presents the minimum-design
               specifications for substation interconnection facilities. GI0005T
               supplements the following requirements:

               5.1.1.1 The control building will be temperature controlled and
                    weatherproof to enclose the AC and DC power sources; the
                    relaying devices; and the telemetering, supervisory RTU, and
                    communication equipment.

               5.1.1.2 The interrupting device will be a power circuit breaker
                    capable of interrupting maximum available fault current or
                    industry-standard minimum levels, whichever is greater. It
                    shall be connected for SPPCo. supervisory control.

                    If the addition of a line tap and extension to the QF's
                    generation adds any appreciable exposure to the existing
                    transmission/distribution facilities, additional circuit
                    breaker(s) may be required at the tap point to mitigate this
                    exposure.

                    Air-break switches will be installed on each side of the
                    circuit breaker to isolate the breaker for inspection and
                    maintenance purposes. Single-breaker schemes will not
                    include bypass provisions. Where lines terminate on
                    switches, ground blades will be required.

               5.1.1.3 The following protective relays will be installed at the
                    interconnection point (minimum requirement). Typical
                    settings required by SPPCo. are defined below. Sierra will

---------------------------------------------------------------------------
                   ENGINEERING & CONSTRUCTION STANDARD    VOL   SECT   PAGE
                                                          -----------------
                                                          1     2.2
[SPPCO. LOGO]             SMALL POWER PRODUCTION          -----------------
                     AND COGENERATION FOR GENERATION                          SHEET 7 OF ___
                         GREATER THAN ONE MEGAWATT        -----------------   --------------

                         SIERRA PACIFIC POWER CO.         -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------
--------------------------------------------------------------------------------

                                   Appendix H
                                     Page 7

                                                         EXHIBIT L (2) - 8 of 12

--------------------------------------------------------------------------------
                    provide site-specific settings prior to interconnection
                    testing.

                    o    Phase and Neutral Overcurrent Relays.

                    o    Over/Undervoltage Relays.

                         Over/undervoltage protection will be set to pick up at
                         +/-111 percent of nominal with a definite time to trip
                         of 3.0 seconds. In addition, the high-speed (0.15
                         second) trip will be initiated if the voltage at the
                         interconnection exceeds 115 percent of nominal.

                    o    Over/Underfrequency Relays.

                         Underfrequency protection will typically be set at 58.0
                         Hz with a time delay of 15 seconds to coordinate with
                         the SPPCo. underfrequency load shedding scheme. The
                         turbine-generator supplied by the QF Developer should
                         be designed to operate at 58.0 Hz for 15 seconds
                         without any loss of life.

                         Overfrequency protection will be set to trip at 61 Hz
                         in three seconds and at 63 Hz in 0.15 seconds.

                    o    Negative Sequence Relay (Loss of Phase).

                         This relay will be set to detect loss of one phase with
                         a generator output down to 20 percent. Tripping time
                         will be dependent upon what other devices must be
                         coordinated with, but a typical value would be
                         three-five seconds.

                    o    Synch-Check Relay.

                         The relay will prevent the circuit breaker from
                         operation under excessive phase-angle differences, and
                         it will limit torques on the QF generator that could
                         damage equipment.

                         Disclaimer - The interconnection protection and
                         settings outlined above are not to be construed as
                         protection of the QF turbine generator. Additional
                         supplementary protection may be required.

               5.1.1.4 A Supervisory Remote Terminal Unit will be installed at
                    the interconnection facility with the necessary interface to
                    connect it to SPPCo.'s communications system. This system
                    will provide telemetering and control.

---------------------------------------------------------------------------
                   ENGINEERING & CONSTRUCTION STANDARD    VOL   SECT   PAGE
                                                          -----------------
                                                          1     2.2
[SPPCO. LOGO]             SMALL POWER PRODUCTION          -----------------
                      AND COGENERATION FOR GENERATION                         SHEET 8 OF ___
                         GREATER THAN ONE MEGAWATT        -----------------   --------------

                          SIERRA PACIFIC POWER CO.        -----------------     DRAWING NO.
                                                                                 2.2 GN 02
                                                          -----------------
--------------------------------------------------------------------------------

                                   Appendix H
                                     Page 8

                                                           EXHIBIT L (2) 9 of 12

--------------------------------------------------------------------------------
                    The following information will be remotely monitored with
                    the telemetering equipment:

                              o    Watts In/Out

                              o    Vars In/Out

                              o    Amps

                              o    KWHr and KVarHr

                              o    Line Voltage at Interconnection

                              o    Interconnection Breaker Status/Control

     5.2  SPPCo. System Modifications Required to Support the QF

          In addition to the above requirements, replacement or upgrade of
          existing protective device(s) at other locations may be necessary as a
          result of the addition of QF generation. This may include breakers,
          relays, controls, and other protective devices.

          Should the QF's generation have the potential to be isolated with a
          portion of the SPPCo. system such that the connected load is less than
          or equal to the output of the generator, additional protection may be
          required. This protection may consist of additional relaying or may
          entail the design of a complete remedial-action scheme utilizing
          transfer tripping or some other method to minimize potential adverse
          effects caused by the QF. Transient study results will dictate the
          extent of additional protection requirements or operating
          restrictions.

     5.3  Extension Line

          If ownership, by. SPPCo., of the extension line is contemplated by the
          QF Developer, the line must be constructed such that it complies with
          SPPCo.'s design, construction, and material standards. In addition,
          all right-of-way and permits will be reviewed and approved by SPPCo.

          The extension line (transmission or distribution) design will be
          submitted by SPPCo. for review to ensure that the proposed
          installation meets the minimum requirements as specified by SPPCo.
          SPPCo. Standard GI0001T defines the minimum design standards for
          transmission lines, and SPPCo. Standard GEN01T defines the minimum
          standards for distribution lines.

     5.4  Customer Design Requirements

          This section provides the minimum requirements that the QF Developer
          must meet for major equipment, design review, and design
          responsibility.

          5.4.1 Codes - The QF Developer's installation must meet all applicable
               national, state, and local building and safety codes. In
               addition, installations shall comply with the National Electric
               Code, National Electric Safety Code (ANSI C2), and ANSI, IEEE,
               and NEMA standards for electrical materials and equipment.

-----------------------------------------------------------------------
                ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                      -----------------
[SPPCO. LOGO]          SMALL POWER PRODUCTION          1    2.2
                  AND COGENERATION FOR GENERATION     -----------------
                     GREATER THAN ONE MEGAWATT                            SHEET 9 OF ___
                                                      -----------------   --------------
                      SIERRA PACIFIC POWER CO.
                                                      -----------------     DRAWING NO.
                                                                             2.2 GN 02
                                                      -----------------

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

                                   Appendix H
                                     Page 9

                                                          EXHIBIT L (2) 10 of 12

--------------------------------------------------------------------------------
          5.4.2 Major Equipment Requirements

               5.4.2.1 Synchronous Generation - Units or groups of smaller units
                    in one location with individual or total aggregate capacity
                    greater than 1 MW must use synchronous generators, with
                    speed-droop governors and high-speed excitation systems.
                    Individual units should have a minimum operating capability
                    of .90 lagging to .95 leading power factor at rated real
                    power output. At times, SPPCo. may require direct or
                    indirect voltage or power factor control of these units to
                    maintain acceptable system operation.

                    Exception:

                    Units or groups of units connected directly to the
                    distribution system (SPPCo.'s 25 kV or below electrical
                    system) must be reviewed for safety, security, and transient
                    response associated with islanding conditions. This review
                    may dictate a requirement for induction rather than
                    synchronous generation. SPPCo. will specify induction or
                    synchronous generation in these cases subsequent to the
                    interconnection/transient studies.

                    5.4.2.1.1 Individual generators 1 MW or larger are required
                         to have speed-droop governors with a permanent droop
                         setting of 5%. While synchronized to SPPCo.'s
                         electrical system, the governor will operate in droop
                         mode and shall not be blocked without prior permission
                         from SPPCo. Separate generation controllers will have
                         to be reviewed and approved before the unit will be
                         allowed to go into service.

                    5.4.2.1.2 Individual generators 1 MW or larger should have
                         excitation systems with operational, continuously
                         acting (IEEE Def. 2.12.1), automatic voltage
                         regulators. Voltage regulators shall not be left in
                         non-automatic operation without prior permission from
                         SPPCo. The voltage response ratio (IEEE Def. 3.18 and
                         3.21) of said systems are required to be .5 or greater.
                         The facility developer/owner must supply SPPCo. with
                         test results documenting the response ratio
                         performance. SPPCo. reserves the right to determine, on
                         an individual basis, whether a generators excitation
                         system is accentable,

                    5.4.2.1.3 Individual generators 1 MW or larger may be
                         required to have a power factor regulator.
                         Determination of this requirement will be performed by
                         SPPCo.

-----------------------------------------------------------------------
                ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                      -----------------
[SPPCO. LOGO]          SMALL POWER PRODUCTION          1    2.2
                  AND COGENERATION FOR GENERATION     -----------------
                     GREATER THAN ONE MEGAWATT                            SHEET 10 OF ___
                                                      -----------------   ---------------
                      SIERRA PACIFIC POWER CO.
                                                      -----------------     DRAWING NO.
                                                                             2.2 GN 02
                                                      -----------------

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

                                   Appendix H
                                     Page 10

                                                          EXHIBIT L (2) 11 of 12

--------------------------------------------------------------------------------
                    5.4.2.1.4 Individual generators with a capacity less than 75
                         MW may be required to have power system stabilizers
                         installed with their excitation systems. The
                         determination will be performed by SPPCo. and will be
                         dependent on the location of the facility, excitation
                         system type and performance relative to SPPCo.'s
                         electrical network.

                    5.4.2.1.5 Individual generators 75 MW or larger are required
                         to have power system stabilizers (PSS) installed with
                         their excitation systems. The PSS must be calibrated
                         and operated in accordance with Western Systems
                         Coordinating Council (WSCC) standard procedures for
                         calibration, testing, and operation of PSS equipment.
                         In addition, the calibration and test reports must be
                         submitted to SPPCo.'s Transmission Planning Department
                         for review and approval. The facility will not be
                         considered operational until calibration of the PSS has
                         been performed to SPPCo.'s satisfaction. A copy of the
                         WSCC Power System Stabilizer Test Procedures may be
                         obtained from SPPCo.

               5.4.2.2 Power Transformer - All step-up power transformers
                    connected to SPPCo.'s system must have a grounded wye
                    high-voltage winding. It is recommended that the low-voltage
                    winding (generator side) of the step-up transformer be a
                    delta connection. The nominal voltage ratings (high side and
                    BIL) must be compatible with the system voltages on the line
                    to which it is attached. Where low-side metering will be
                    utilized, certified test results detailing the losses of the
                    transformer must be provided to SPPCo.

          5.4.3 It is the responsibility of the QF Developer to incorporate the
               following information into the design of their generation
               facility. The QF Developer should not limit their design to only
               these items.

               5.4.3.1 Full Load Rejection - The QF Developer's generation
                    facility must be designed with the capability or protection
                    to withstand sudden loss of load.

               5.4.3.2 Primary Voltage Changes - The generator exciter system
                    and voltage regulation equipment on synchronous generators
                    must be capable of operating subject to normal primary
                    voltage changes on SPPCo.'s system ranging from 7.5 percent
                    above or below nominal primary voltage to +/-10 percent
                    during emergency conditions. During a disturbance, the
                    voltage may fluctuate beyond the 10 percent range. Equipment
                    that is not capable of withstanding these excursions should
                    be protected.

-----------------------------------------------------------------------
                ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                      -----------------
[SPPCO. LOGO]          SMALL POWER PRODUCTION         1     2.2
                  AND COGENERATION FOR GENERATION     -----------------
                     GREATER THAN ONE MEGAWATT                            SHEET 11 OF ___
                                                      -----------------   ---------------
                      SIERRA PACIFIC POWER CO.
                                                      -----------------     DRAWING NO.
                                                                             2.2 GN 02
                                                      -----------------

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

                                                        EXHIBIT L (2) - 12 of 12

--------------------------------------------------------------------------------
               5.4.3.3 Harmonics - The QF Developer's generation facility shall
                    not cause unacceptable distortion of the sinusoidal voltage
                    or current wave form. The maximum allowable total harmonic
                    voltage (all harmonics) and current distortion cannot exceed
                    the values published in IEEE Standard 519.

               5.4.3.4 Voltage Sag - Motor starting and switching operations are
                    limited so that the momentary voltage sag (flicker) during
                    motor starting or switching does not exceed 4 percent of the
                    nominal system voltage for any other customers.

     5.5  Proposed Design Review

          The QF Developer shall submit, for SPPCo.'s review, a generation
          facility one-line diagram, approved by a registered professional
          engineer, indicating the QF's protective devices and their functions.
          Current and potential transformer ratios must be included on the
          on-line diagram when required. In addition, protective device types,
          styles, and settings must be provided. The review is intended to
          ensure that the proposed installation meets the minimum requirements
          to protect SPPCo.'s system from misoperations of the generating unit.
          SPPCo. reserves the right to require additional protective equipment
          and safety measures as further experience may dictate.

     5.6  Synchronizing Equipment

          Synchronizing equipment is required for synchronous generators at the
          interconnection, generator, and other breakers as necessary. The
          generator must be brought on-line parallel to SPPCo.'s system by one
          of the following methods:

          5.6.1 Automatic synchronizing.

          5.6.2 Manual synchronizing - A synch-check relay is required to
               supervise manual closing of the generator circuit breaker.

     5.7  QF Telephone requirements

          The QF Developer is required to install a telephone for direct
          communication with SPPCo.'s Electric System Control Center (ESCC). The
          telephone communication between the QF and ESCC shall be delay free.

--------------------------------------------------------------------------------
                ENGINEERING & CONSTRUCTION STANDARD   VOL   SECT   PAGE
                                                      -----------------
[SPPCO. LOGO]          SMALL POWER PRODUCTION          1    2.2
                  AND COGENERATION FOR GENERATION     -----------------
                      GREATER THAN ONE MEGAWATT                            SHEET 12 OF __
                                                      -----------------    --------------
                       SIERRA PACIFIC POWER CO.
                                                      -----------------      DRAWING NO.
                                                                              2.2 GN 02
                                                      -----------------

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

                                    EXHIBIT M

                   FACILITY WIRING DIAGRAM AND SPECIFICATIONS

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 1 of 8 Pages

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

                                    REVISIONS

Each time a new page is added to this specification, or an existing page is
revised, only this "Revisions" page reissues with the new or revised pages.

REV     DATE     BY   PAGES            REMARKS
---   -------   ---   -----   ------------------------
 A     5/7/91   GKD    All    Issued for Quotation.

 O    7/31/91   GKD    All    Issued for Construction.

                                                  Approved
                                                           ---------------------
                                                              The Ben Holt Co.

                                                           ---------------------
                                                                    TIC

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 2 of 8 Pages

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

1.0  SCOPE

     This Specification covers an outdoor 12.47 kV single-phase, dry type,
     self-cooled, air core shunt reactors continuously operated.

2.0  APPLICATION

     The reactors are for outdoor, concrete pad mounting and to provide
     protection from utility system transient overvoltages. Location - Brady Hot
     Springs, Nevada.

3.0  STANDARDS AND CODES

     The reactors covered by this Specification shall be designed, tested and
     assembled in accordance with the applicable standards of NEMA, IEEE, and
     ANSI and shall conform to the latest edition of the National Electrical
     Code.

4.0  WORKMANSHIP AND MATERIALS

     Materials and equipment shall be standard products of established
     manufacturers who have produced continuously the type of equipment
     specified. All materials and equipment shall be new.

     The unit shall be completely factory built and assembled.

5.0  GUARANTEES

     The components shall be guaranteed for a period of one (1) year from the
     date of their acceptance against defective materials, design and
     workmanship. Upon receipt of notice from the Purchaser of failure of any
     part of the equipment during the guarantee period, new replacement parts
     shall be furnished and installed promptly by the Vendor at no cost to the
     Purchaser.

6.0  ARRANGEMENTS

     Three single-phase reactors will be placed in a triangular configuration,
     wye-connected and fed by a three-phase circuit breaker. The neutral will
     not be grounded. The spacing between the reactors will be as shown on Sheet
     7.

7.0  RATINGS

     The reactors shall be self-cooled, outdoor dry type, air core and of
     upright design, and designed to industry standards and shall include the
     following:

     A.   Rating: 2.17 MVAR (Total 3 (phi) rating of 6.5 MVAR).

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 3 of 8 Pages

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

     B.   Class: Self-cooled (Class AA as defined in ANSI C57.21).

     C.   Number of phases per reactor: One.

     D.   Temperature rise of windings and terminals: 80 DEG.C with
          hottest-spot temperature rise of 110 DEG.C at 110% rated voltage.

     E.   Frequency: 60 Hz.

     F.   Rated voltage: 12.47 kV, wye-connected.

     G.   Overvoltage: 10 percent continuous above and below rated voltage
          without exceeding the temperature rise limits specified in "D", above.

     H.   Insulation class: 15 kV.

     I.   BIL: 110 kV.

     J.   Type of insulation: Class B as specified in ANSI C57.12.80.

     K.   Temperature rise is with reference to an average ambient of
          30 DEG.C.

     L.   Altitude of 4100'.

8.0  PHYSICAL REQUIREMENTS

     8.1  All materials used in the shunt reactors shall be impervious to
          moisture and shall be suitable for outdoor service.

     8.2  The overall diameter of the shunt reactors shall not exceed 7 feet, 6
          inches, unless specifically approved by The Ben Holt Co.

     8.3  Reactors shall be fitted with lifting eyes or other suitable means for
          lifting with a crane.

     8.4  Reactors which have a base shall be provided with a drainage hole in
          the center of the base. The base should be designed such that it
          slopes toward the drainage hole, or a removable base will be accepted.

9.0  INSULATORS AND NONMAGNETIC SPACERS

     9.1  The shunt reactors shall be mounted on insulators and nonmagnetic
          spacers. The insulators and spacers shall be furnished by
          Manufacturer. Any other mounting method must be approved by The Ben
          Holt Co.

          9.1.1 The insulators shall have nonmagnetic caps and be of sufficient
               strength and size to meet the seismic requirements specified

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 4 of 8 Pages

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

               in Section 15. In no case shall insulators smaller than 10 inches
               in diameter be used.

          9.1.2 The nonmagnetic spacers shall be 13 inches high. The temperature
               rise shall be below the values permitted by 7 D and shall not
               damage the porcelain, metal parts, cement, sealant, or other
               components of the insulators.

     9.2  Manufacturer shall furnish information relative to the insulators,
          dimensions, and spacing around the periphery of the bottom of the
          reactors.

10.0 WINDINGS

     10.1 The windings of the reactors shall be aluminum, without joints.

     10.2 The clearance between adjacent turns shall be not less than 1/4 inch,
          unless approved by The Ben Holt Co.

11.0 TERMINALS AND TERMINAL CONNECTORS

     11.1 The terminals of the reactors shall be either brazed or welded to the
          windings.

     11.2 With the conductor arrangement shown on Page 7, the terminals,
          together with the reactors, shall be capable of withstanding an
          available short-circuit duty of 500 MVA.

     11.3 The terminals shall be tin plated.

     11.4 The design of the terminals and the method by which they are secured
          to the reactors shall be such that they will safely support the cables
          and connectors, the sizes of which are shown on Page 7. Manufacturer
          shall assure that the terminals will not bend or be pulled away from
          the reactors. The Apparatus may be subjected to maximum steady wind
          velocities of 88 miles per hour and gusting wind velocities of 120
          miles per hour. Reactor conductors shall withstand normal reactor
          vibration.

     11.5 The temperature rise of the terminals shall not exceed the temperature
          limits permitted for the windings.

     11.6 Manufacturer shall furnish information showing the location of the
          terminals relative to the mounting insulators.

     11.7 Terminal connectors for connection to cables will be furnished by The
          Ben Holt Co.

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 5 of 8 Pages

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

12.0 AUDIBLE NOISE LEVEL

     The average audible sound level of any single-phase shunt reactor shall not
     exceed 60 dBA. The audible sound level shall be measured at a distance of
     50 feet from the centerline of the reactor. There shall be no obstructions
     between the reactor and sound measuring apparatus. Sound level tests shall
     be performed as specified in proposed Section 12.6 of ANSI C57.21.

13.0 NAMEPLATES

     Each shunt reactor shall have a noncorrosive, nonmagnetic, stainless steel
     nameplate permanently attached which shall show, as a minimum, the data
     specified in ANSI C57.21. Adhesive type nameplates and labels are not
     acceptable.

14.0 TESTS

     Manufacturer shall make the following tests and furnish three certified
     copies of the test data:

     14.1 Losses and Impedance: In accordance with ANSI C57.21.

     14.2 Temperature Rise Tests: In accordance with ANSI C57.21. The test shall
          be performed at 110% rated voltage.

     14.3 Resistance Measurements: In accordance with ANSI C57.21.

     14.4 Applied Potential Tests: Made on all units in accordance with ANSI
          C57.21.

     14.5 Impulse Tests: In accordance with ANSI C57.21.

15.0 SEISMIC CAPABILITY

     The reactors shall be designed for Zone 4.

16.0 DATA, DRAWINGS, MANUALS AND TEST REPORTS

     16.1 Data and Drawings

          Supplier shall submit data and drawings within the number of days
          after notification of award as specified.

          Outline drawings shall include all the information listed below:

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 6 of 8 Pages

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

          A.   Location of insulators.

          B.   Mounting hole dimensions of the bottom insulators.

          C.   The location of terminals relative to the mounting insulators.

          D.   Location and dimensions of the terminal pads.

          E.   Information relative to the number of insulators, dimensions, and
               spacing around the periphery of the bottom of the reactors.

          F.   Diameter of insulators, overall height, and height above the
               mounting insulators.

     16.2 Manuals

          Supplier shall submit complete instruction manuals, including parts
          lists, for the reactors and all devices and equipment furnished with
          the reactors. The manuals shall give complete and detailed
          instructions for erection, installation, operation, adjustment and
          maintenance.

     16.3 Test Reports

          Supplier shall submit certified test reports for all specified tests.

17.0 INFORMATION WITH PROPOSAL

     Bidders shall furnish, as a part of their proposal, two (2) copies of each
     of the items listed below pertaining to the equipment they propose to
     furnish.

     17.1 Descriptive bulletins.

     17.2 Sketches showing the arrangement and overall dimensions.

     17.3 Weight.

     17.4 Sound levels.

     17.5 Reactor losses at no load and full load.

18.0 HYDROGEN SULFIDE GAS CONTAMINATION

     During plant operation the equipment will be exposed intermittently to
     varying concentrations of hydrogen sulfide gas and geothermal fluid spray
     from venting operations. These conditions will be extremely corrosive to
     silver, copper and copper based alloys. The equipment furnished shall be

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 7 of 8 Pages

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

18.0 HYDROGEN SULPIDE GAS CONTAMINATION (Continued)

     suitable for operation under these environmental conditions. Copper or
     copper alloy parts shall be tinned or coated with a permanent suitable
     coating to protect against hydrogen sulfide. Aluminum may be substituted
     for copper where it is practical to do so. All exposed copper or wiring
     shall be tinned coated.

DRY TYPE AIR CORE SHUNT REACTOR                        Specification No. 3600-13

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     July 31, 1991
                                                              Page 8 of 8 Pages

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

                                     SKETCH

                                    [GRAPHIC]

                            REACTOR ARRANGEMENT PLAN

No SCALE

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 1 of 6 Pages

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

                                    REVISIONS

Each time a new page is added to this specification, or an existing page is
revised, only this "Revisions" page reissues with the new or revised pages.

REV.     DATE      BY   PAGES   REMARKS
----   --------   ---   -----   -----------------------------------
  A    11/12/90   GKD    All    Issued for Quotation.
  B    04/23/91   GKD    All    Added Fans and Issued for Contract.
  O    07/25/91   GKD    All    Issued for Purchase.

                                                  Approved
                                                          ----------------------
                                                              The Ben Holt Co.

                                                          ----------------------
                                                                   TIC

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 2 of 6 Pages

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

1.0  SCOPE

     This Specification covers an outdoor 120KV/12.47KV substation transformer,
     complete from the high voltage bushings to the low-voltage bus terminals.

2.0  APPLICATION

     This substation is a generator step-up transformer, outdoor, concrete pad
     mounting, 12.47 KV to 120 KV. Location: Brady Hot Springs, Nevada.

3.0  STANDARDS AND CODES

     The substation covered by this Specification shall be designed, tested and
     assembled in accordance with the applicable standards of NEMA, IEEE, and
     ANSI and shall conform to the latest edition of the National Electrical
     Code.

4.0  WORKMANSHIP AND MATERIALS

     Materials and equipment shall be standard products of established
     manufacturers who have produced continuously the type of equipment
     specified. All materials and equipment shall be new.

     The unit shall be completely factory built and assembled.

5.0  GUARANTEES

     The components shall be guaranteed for a period of one (1) year from the
     date of their acceptance against defective materials, design and
     workmanship. Upon receipt of notice from the purchaser of failure of any
     part of the equipment during the guarantee period, new replacement parts
     shall be furnished and installed promptly by the vendor at no cost to the
     purchaser.

6.0  ARRANGEMENT

     6.1  The 120KV side of the transformer shall consist of cover mounted extra
          creapage bushings with areal lugs suitable for #2 ACSR wire and
          bushings to be provided with 400/5 multi-ratio current transformers
          for differential protection. 84 KV metal oxide station type surge
          lightning arrestors to be provided for mounting on top of transformer.

          The primary neutral bushing shall be covered mounted, 110 KV BIL
          rated.

          Provide one multi-ratio bushing type current transformer in the
          neutral bushing. The current transformer ratio shall be 200 to 5
          Amperes maximum.

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 3 of 6 Pages

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

          Provide wiring from current transformer to identified terminals in a
          box mounted on the transformer. The box shall include at lease one 3/4
          inch, or larger, conduit entrance for use by the customer.

     6.2  The 12.47 KV side of the transformer shall consist of sidewall
          bushings and enclosed in a standard flanged enclosure for connection
          to a 1600 Ampere, 15 KV metal enclosed bus. Flexible bus connectors
          will be provided with the metal enclosed bus. The bushing tangs and
          the flanged enclosure shall be factory drilled to match like
          components on the metal enclosed bus.

7.0  RATING. PROVISIONS AND ACCESSORIES

     The transformer shall be an oil-immersed, self-cooled, outdoor unit,
     designed to industry standards and shall include the following:

Ratings                22.32 MVA / 25 MVA / 29.7 MVA (F.A.)

Temperature Rise       OA 55 DEG./ OA 65 DEG./ FA 65 DEG.

Frequency              60 Hertz

Phases                 3

High Voltage           120 KV

H.V. Connection        WYE

Low Voltage            12.47 KV

LV. Connection         DELTA

Impedance              8%

H.V. Taps              4 - 2-1/2% (Two above and two below, fully rated.

Standard Accessories   (Noted in 8.4)

Fans                   Fan cooling shall be provided. Capacity in all current
                       carrying parts shall be based on the fan cooled rating.

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 4 of 6 Pages

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

8.0  CHARACTERISTICS

     8.1  Temperature rise is with reference to an average ambient of
          30 DEG. C.

     8.2  120 KV transformers shall be of 138 KV insulation class with a minimum
          of 550 KV BIL rating and 12.47 KV shall be 110 KV BIL.

     8.3  No-load tap changers shall be externally operable and rated for full
          transformer KVA and capable of being locked in any position.

     8.4  Standard accessories shall include the following:

          o    Liquid level gauge.

          o    Dial-type thermometer with high temperature switch for actuation
               of fans and alarms.

          o    One oil thermal relay.

          o    One winding thermal relay.

          o    Drain and lower filter-press valve.

          o    Pressure relief device.

          o    Lifting eyes or hooks.

          o    Tank grounding pads.

          o    Base of transformer shall be capable of skidding in any
               direction, and furnished with jacking facilities.

          o    Cove handholes.

          o    Pressure vacuum gauge.

          o    Pressure vacuum bleeder.

          o    Upper filter-press valve.

          o    Gas sampling valve.

          o    Stainless steel nameplate, with ratings, description and
               instructions.

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 5 of 6 Pages

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

9.0  ACCESSORIES

     Provide a fault pressure relay, device 63, on the transformer. The relay
     shall close its contacts on an abnormal rate of change in pressure. A
     source if 125 V DC power if required for this devide is available.

     Provide wiring for all current transformers and the fault pressure relay to
     identified terminals in a box mounted on the transformer. The box shall
     include at least one 3/4 inch, or larger, conduit entrance for use by the
     customer.

10.0 PAINTING

     All metal parts of the complete transformer shall be thoroughly cleaned
     before application of a rust inhibitor. A minimum of two (2) MILS thickness
     of vendor's standard finish for transformers shall be applied. Furnish one
     pint of finish paint for field touch-up.

11.0 TESTS AND INSPECTION

     11.1 The equipment shall be submitted to standard commercial factory tests
          to assure operational performance.

     11.2 The owner reserves the right of inspection in the manufacturer's shop
          during testing.

     11.3 The manufacturer shall, if requested, provide the services of a field
          engineer to supervise any field tests and to make necessary adjustment
          or alterations, required for the operation of the equipment in
          accordance with this Specification.

12.0 ALTITUDE AND AMBIENT REQUIREMENTS

     Equipment shall be designed to conform to the following:

     Altitude: 4,100 feet above sea level
     Ambient temperature: 110 DEG. F Max. to 20 DEG. F Min.

     Primary voltage changes at full load will be +/- 10 percent.

                                    EXHIBIT N

                          FINAL INTERCONNECTION WIRING

                                                                   Attachment #4
                                                                       Exhibit O
                                                                 Amendment No. 1
                                                                     Page 1 of 2

Item   Date      Milestone                   Standard                    Documentation
----   -------   -------------------------   -------------------------   -------------------------

No.l   9/16/91   Issue purchase order for    Purchase order with         Provide Sierra with a
                 the turbine generators      vendor indicating           copy of purchase order
                                             requisition of              from vendor with a
                                             turbine/generator sets      specified delivery date

No.2   2/5/92    Receive UEPA permit         Order from Public Service   Provide notice of verbal
                 approval from the Public    Commission of Nevada        approval by the Public
                 Service Commission of       granting the Project        Service Commission of
                 Nevada                      rights for construction     Nevada for UEPA permit,
                                                                         followed with the written
                                                                         decisions from the agenda
                                                                         hearing where the
                                                                         approval was made

No.3   2/5/92    Completion of drilling of   Complete the drilling of    Provide Sierra with the
                 the initial production      the initial production      data from the well test,
                 well(s) to be used for      well(s), which shall        which test is performed
                 the Project                 deliver dry steam at not    by qualified
                                             less than _(1)_ pounds      professionals, which
                                             per hour at a pressure of   indicates delivery of dry
                                             not less than _(3)_ and a   steam of quality and
                                             temperature of not less     quantity as indicated
                                             than _(3)_ degrees F for
                                             a test period of 48
                                             continuous hours or until
                                             stabilization occurs.
                                             Stabilization shall be
                                             considered met when the
                                             pressure at the end of
                                             any 8-hour continuous
                                             period shall not be more
                                             than 1 psi less than the
                                             first hour of the 8-hour
                                             period

No.4   3/20/92   Begin pouring of turbine/   Complete preparation of     Provide documentation by
                 generator foundations       turbine/generator           a qualified professional
                                             foundation and begin        that the foundation is
                                             pouring of concrete for     prepared and that
                                             mounting of                 concrete pouring has
                                             turbine/generator sets      begun

No.5   5/18/92   Delivery of                 Receipt of                  Provide documentation
                 turbine/generators to the   turbine/generator sets      that the turbine/
                 plant site of the Project   from vendor delivered to    generator sets has been
                                             plant site                  delivered to plant site

No.6   5/23/92   Complete installation of    Complete mounting of        Provide documentation
                 turbine/generators          turbine/generator sets on   from a qualified
                                             foundation                  professional that the
                                                                         turbine/ generators has
                                                                         been mounted and set on
                                                                         the foundation

                                                                   Attachment #4
                                                                       Exhibit 0
                                                                 Amendment No. 1
                                                                     Page 2 of 2

Item   Date      Milestone                   Standard                    Documentation
----   -------   -------------------------   -------------------------   -------------------------

No.7   5/25/92   Completion of well          Complete the drilling of    Provide Sierra with the
                 drilling for all wells to   all production and          data from the well tests,
                 be used for the Project     injection wells, which      which tests are performed
                                             shall deliver dry steam     by certified
                                             of not less than _(2)       professionals, which
                                             pounds per hour at a        indicates the delivery of
                                             pressure of not less than   dry steam of quality
                                             _(3)_ and a temperature     and quantity as indicated
                                             of not less than _(3)_      and capability of
                                             degrees F, and shall be     injection of all
                                             capable of injecting all    production fluids from
                                             fluids produced by the      the Project
                                             production wells

No.8   9/20/92   Commence the thirty day     Begin thirty day            Provide notice to Sierra
                 shakedown period as         shakedown period pursuant   pursuant to Section 7 of
                 described in Section 7 of   to Section 7 of the         the Agreement that the
                 the Agreement               Agreement                   shakedown period has
                                                                         begun

No.9   11/20/92  Achieve a Commercial        Perform 100-hour test       Provide notice to Sierra
                 Operation Date pursuant     pursuant to Section 7 of    pursuant to Section 7 of
                 to Section 7 of the         the Agreement & establish   the Agreement that the
                 Agreement                   a Commercial Operation      Commercial Operation date
                                             date                        has been established

1)   Calculated as: 120% of the steam number provided in Section 9(b) divided by
     11 (eleven was the total number of wells proposed).

2)   Calculated as: 120% of the steam number provided in Section 9(b).

3)   These numbers shall correspond to the numbers provided in Section 9(b).

                                                                       EXHIBIT P

                           SEMI-ANNUAL PROJECT REPORT

Monthly Data: Required for production and injection wells.

     Total production to plant (gmp) or lbs/hr) ________________________________
     Total plant output (kwh) ___________________________
     Pressure at inlet __________________________________
     Temperature at inlet _______________________________

Production well:

a)   Flowing/pumping:

     Steam ___________________________
     Water ___________________________
     Non-condensible gas concentration _________________________
     Reservoir well head pressure ______________________________
     Reservoir well head temperature ___________________________
     Operating time __________________

a)   Static:

     Shut-in pressure or fluid levels __________________________
     Shut-in temperature _______________________________

Injection well:

     Pressure ________________________
     Volume __________________________

Data needed 3 times a day from any observation well(s):

     Pressure ________________________
     Fluid Level _____________________

Following data record as it happens:

                     What and When Occurred   Cost (Repair)

Plant outage         ______________________   _____________
Unit outage          ______________________   _____________
Equipment failures   ______________________   _____________
Scale removal        ______________________   _____________

Future Data

o    Plans to drill any type of well ______________________

o    Plans for descaling __________________________________

o    Plant modification and refurbishments ________________

o    Any modification of plant ____________________________

LIQUID FILLED SUBSTATION TRANSFORMER A                  Specification No. 3600-8

Nevada Geothermal Power Partners, Ltd.                        Holt Job No. 20177
Brady Hot Springs, Nevada                                     April 23, 1991
                                                              Page 6 of 6 Pages

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

13.0 INFORMATION WITH PROPOSAL

     13.1 Descriptive bulletins

     13.2 Sketches showing the arrangement and overall dimensions

     13.3 Weight

     13.4 Sound Levels

     13.5 Standard Tests

     13.6 Transformer Losses at no load, 3/4 load and full loadEXECUTION COPY

                       AMENDED AND RESTATED OPERATION AND
                             MAINTENANCE AGREEMENT

                                     BETWEEN

                                  ORNI 7, LLC,

                            STEAMBOAT GEOTHERMAL LLC

                                       AND

                                ORMAT NEVADA INC.

                          Operation and Maintenance Agreement - Steamboat Plants

                                STEAMBOAT PROJECT

                                       USA

                                TABLE OF CONTENTS

SECTION 1  - DEFINITIONS AND RULES OF INTERPRETATION...........................2
SECTION 2  - WORK SCOPE........................................................7
SECTION 3  - RESPONSIBILITIES AND RIGHTS OF OWNER.............................12
SECTION 4  - PAYMENTS.........................................................16
SECTION 5  - BILLING..........................................................19
SECTION 6  - FORCE MAJEURE....................................................20
SECTION 7  - ENVIRONMENTAL RESPONSIBILITIES...................................22
SECTION 8  - TERM AND TERMINATION.............................................24
SECTION 9  - INDEMNIFICATION..................................................26
SECTION 10 - LIMITATION OF LIABILITY..........................................29
SECTION 11 - INSURANCE........................................................30
SECTION 12 - ASSIGNMENT.......................................................32
SECTION 13 - REPRESENTATIONS, WARRANTIES AND COVENANTS........................32
SECTION 14 - SUBCONTRACTORS...................................................35
SECTION 15 - MISCELLANEOUS....................................................35

Steamboat Project O&M

                          Operation and Maintenance Agreement - Steamboat Plants

            AMENDED AND RESTATED OPERATION AND MAINTENANCE AGREEMENT

     This AMENDED AND RESTATED OPERATION AND MAINTENANCE AGREEMENT is made and
entered into as of this 8th day of December, 2003, by and between:

     ORNI 7, LLC, a limited liability company incorporated in the State of
Delaware, with offices at 980 Greg Street, Sparks, Nevada 89431-6039 and
STEAMBOAT GEOTHERMAL LLC, a limited liability company incorporated in the State
of Delaware, with offices at 980 Greg Street, Sparks, Nevada 89431-6039
(collectively - "Owner")

                                     - and -

     ORMAT NEVADA INC., a corporation incorporated in the State of Delaware,
with offices at 980 Greg Street, Sparks, Nevada 89431-6039 ("Operator").

     Each such entity may be individually referred to herein as a "Party" and
both Owner and Operator may be collectively referred to herein as the "Parties".

     WHEREAS, Owner, directly or through its affiliates, owns or holds interests
in several geothermal electricity production plants located at Steamboat
Springs, Washoe County, Nevada;

     WHEREAS, electricity produced by the aforementioned power plants is sold to
Sierra Pacific Power Company pursuant to certain power purchase agreements
(specifically, the Agreement for the Purchase and Sale of Electricity between
Steamboat Geothermal LLC (as successor in interest) and Sierra Pacific Power
Company as of November 18, 1983 ("Steamboat 1 PPA"), the Long Term Agreement for
the Purchase and Sale of Electricity between Steamboat Geothermal LLC (as
successor in interest) and Sierra Pacific Power Company as of October 29, 1988
("Steamboat 1A PPA"), the Long Term Agreement for the Purchase and Sale of
Electricity between First Interstate Bank of Nevada, N.A. in its capacity as
Lease Trustee (as successor in interest) and Sierra Pacific Power Company as of
January 24, 1991, as subsequently amended on

Steamboat Project O&M

                                       1

                          Operation and Maintenance Agreement - Steamboat Plants

October 29, 1991, and the Long Term Agreement for the Purchase and Sale of
Electricity between First Interstate Bank of Nevada, N.A. in its capacity as
Lease Trustee (as successor in interest) and Sierra Pacific Power Company as of
January 18, 1991, as such agreements may be amended, restated or supplemented
from time to time in accordance with the respective terms thereof, including the
replacement of the Steamboat 1 PPA and the Steamboat 1A PPA by an additional
power purchase agreement for a project to be known as the "Galena" project,
which will enhance and substitute portions of the existing Steamboat 1 and
Steamboat 1A (together, the "Power Purchase Agreements"));

     WHEREAS, the operation and maintenance of the aforementioned power plants
and associated wells will be undertaken by the Operator upon such terms and
conditions as agreed between the Operator and Owner;

     WHEREAS, this Amended and Restated Operation and Maintenance Agreement
supersedes and replaces the original Operation and Maintenance Agreement dated
as of 8 December, 2003 by and between between Orni 7, LLC and Ormat Nevada,
Inc.; and

     WHEREAS, each of the entities comprising Owner and Operator acknowledges
and consents that, after the acquisition of ownership of Steamboat Development
Corp. by an Owner entity or Affiliate, Steamboat Development Corp. is entitled
to become an additional Owner party to this Agreement.

     NOW, THEREFORE, in consideration of the mutual covenants contained herein
and other good and valuable consideration, the receipt and sufficiency of which
are hereby acknowledged, the Parties, intending to be legally bound, hereby
agree as follows:

SECTION 1 - DEFINITIONS AND RULES OF INTERPRETATION

Steamboat Project O&M

                                       2

                          Operation and Maintenance Agreement - Steamboat Plants

     1.1 As used in this Agreement the following capitalized terms shall have
the meanings set forth below. All references herein to agreements and other
contractual instruments shall be deemed to include all exhibits and appendices
attached thereto and all amendments and other modifications to such agreements
and instruments.

          AFFILIATE: With respect to any Party hereto, any entity that directly
or indirectly: (a) owns or controls such Party, (b) is owned or controlled by
such Party, or, (c) is under common ownership or control with such party. For
purposes of this definition, "control" shall mean the power to direct the
management or policies of such entity, whether through the ownership of voting
securities, by contract or otherwise. For the purpose of this Agreement, Owner
and Operator shall not be deemed to be Affiliates of each other.

          APPLICABLE LAW: All U.S. federal and Nevada state laws, rules,
regulations, orders and interpretations thereof of any national, municipal,
regional, environmental or other governmental body, instrumentality, agency,
authority, court or other body, in each case to the extent the same has
jurisdiction over Operator in connection with its performance under this
Agreement, or over the Steamboat Facility or the Wells.

          ASSOCIATED PLANT OPERATING AGREEMENTS: Shall mean any plant connection
agreements, under which the Steamboat Facility is connected to an electrical
system for delivery of electricity at the relevant point(s) of interconnection
and/or delivery, any plant transmission services agreements and water supply
and/or sewage disposal agreements for the Steamboat Facility.

          AUTHORIZATIONS: Any approval, consent, license, permit, authorization
or other permissions granted by an authorized governmental authority, in each
case to the extent the same has jurisdiction over the Steamboat Facility or the
Wells, including their operation, the transmission or sale of electricity, or
the performance of Owner and Operator under this Agreement.

Steamboat Project O&M

                                       3

                          Operation and Maintenance Agreement - Steamboat Plants

          BANKRUPTCY: The occurrence of any of the following events: (a) the
passing of a resolution by the shareholders of the Owner or of the Operator for
the winding up of the Owner or the Operator, as appropriate; (b) the admission
in writing by the Owner or the Operator, as appropriate, of its general
inability to pay its debts as they become due; (c) the appointment of a
provisional manager, trustee or liquidator in a winding up proceeding after
notice to the Owner or the Operator, as appropriate, which has not been removed
or dismissed within 60 (sixty) days of the date of such appointment; or (d) the
making by a court of competent jurisdiction of an order winding up the Owner or
the Operator, as appropriate, which has not been stayed or vacated within 60
(sixty) days of the date of such order.

          CONFIDENTIAL INFORMATION: Shall have the meaning set forth in Section
15.12.

          EFFECTIVE DATE: The closing date for the purchase by Owner or an Owner
Affiliate of the geothermal power plants known as "Steamboat 2" and "Steamboat
3".

          EMERGENCY MANAGEMENT POWERS: Shall have the meaning set forth in
Section 2.4.

          EXTRAORDINARY OPERATION EXPENSES: The extraordinary expenses of
operation and maintenance of the Facility and the Wells for which Operator shall
be reimbursed by Owner, as provided in Section 4.1.2, including the mark-up as
provided in Section 4.1.2.

          FORCE MAJEURE: Shall have the meaning set forth in Section 6.1.

          GEOTHERMAL FLUID: The hot brine to be supplied to Operator by Owner.

          INDEMNITEE: Shall have the meaning set forth in Section 9.3.

          INDEMNITOR: Shall have the meaning set forth in Section 9.3.

Steamboat Project O&M

                                       4

                          Operation and Maintenance Agreement - Steamboat Plants

          INJECTATE: The geothermal brine to be received from Operator by Owner
for reinjection.

          LEASES: The geothermal resources leases (and subleases), rights of
way, site licenses (including for construction and operation) and other real
property rights related to the Steamboat Facility and the Wells, held by or
available to Owner or its Affiliates.

          LENDER(S): Any entity or entities providing construction or permanent
debt financing for the Steamboat Facility, any trustee or agent acting on behalf
of any such entity or entities, and any successor or permitted assign of any
such entity.

          MAJOR CORRECTIVE MAINTENANCE WORK: Corrective maintenance work which
needs to be performed pursuant to a failure of a major piece of equipment, that
was not a result of normal wear and tear, or Operator gross negligence or
willful misconduct, provided, however, that the use or replacement of
consumables in ordinary amounts is not a Major Corrective Maintenance Work.

          OPERATION FEE: The fixed fee which Owner shall pay to Operator
throughout the Term for operation of the Steamboat Facility and the Wells, as
provided in Section 4.1.1.

          OPERATOR'S INVOICE: A written document provided by Operator to Owner
on a monthly basis requesting payment of the Operation Fee, Extraordinary
Operation Expenses and other costs and expenses payable to Operator hereunder.

          PLANTS MANAGER: Operator's representative for the Facility, who shall
be Operator's single point of contact with Owner in respect of this Agreement
and shall have the requisite level of skill to supervise the performance of
Operator's services hereunder and is authorized to direct the performance of the
Work by Operator.

Steamboat Project O&M

                                       5

                          Operation and Maintenance Agreement - Steamboat Plants

          POWER PURCHASE AGREEMENTS: Shall have the meaning described in the
Preamble of this Agreement.

          QUARTERLY OPERATIONS REPORT: The quarterly report from Operator to
Owner describing Operator's activities at the Facility and the Wells, as
described in Section 2.1.13.

          STEAMBOAT FACILITY or FACILITY: The geothermal production facility
located in Steamboat Springs, Washoe County, the State of Nevada, USA, which
includes power plants formerly known as Steamboat 1, 1A, 2 and 3, of a total
aggregate net capacity of approximately 34 MW, including the electricity
generating stations, associated geothermal piping and carrying systems and
reinjection pumping stations of the plants, including improvements and
replacements which may be made in the future to the Steamboat Facility by
execution of a "Steamboat Enhancement Project" and/or by dismantling and
replacing the Steamboat 1 and Steamboat 1A Plants by a new geothermal plant to
be known as the "Galena" plant.

          TERM: The period defined in Section 8.1.

          UNITED STATES DOLLARS, US DOLLARS or USD: The lawful currency of the
United States of America.

          WELLS: All geothermal wells (whether used for production, injection or
monitoring) located on land held subject to the Leases.

          WORK: Shall mean those specific items which Operator agrees to perform
during the Term, as set forth in Section 2.1.

          YEAR: The period from January 1 to December 31 inclusive, provided,
however, that the first Year of the Term shall commence upon the Effective Date,
and the last Year of the Term shall end upon the date which is the last day of
the Term of this Agreement.

Steamboat Project O&M

                                       6

                          Operation and Maintenance Agreement - Steamboat Plants

     1.2 Terms defined in a given number, tense or form shall have the
corresponding meaning when used in this Agreement with initial capitals in
another number, tense or form. Except as otherwise expressly noted, reference to
specific Sections, subsections, appendices and exhibits are references to such
provisions of or attachments to this Agreement. References containing terms such
as "hereof", "herein", "hereto", "hereinafter", and other terms of like import
are not limited in applicability to the specific provision within which such
references are set forth but instead refer to this Agreement taken as a whole.

SECTION 2 - WORK SCOPE

          2.1  WORK

               During the Term, Operator shall perform the following obligations
and provide the following work and services:

               2.1.1 Designate or cause to be designated a qualified Plants
Manager, who shall be responsible to supervise and direct the performance of the
Operator hereunder.

               2.1.2 Obtain and maintain the insurance policies set forth in
Section 11.1 hereto.

               2.1.3 At Owner's cost and expense, obtain and maintain all
required Authorizations to be maintained by Owner and Operator.

               2.1.4 Directly or indirectly employ and train personnel who will
be qualified and experienced to operate and maintain the Facility and the Wells
and to coordinate operation of the Facility as required under the Power Purchase
Agreements. Operator shall have the right to dismiss any of such personnel, and
shall hire suitable replacement personnel. Operator shall replace any of its
personnel to whom Owner reasonably objects on grounds of

Steamboat Project O&M

                                        7

                          Operation and Maintenance Agreement - Steamboat Plants

his/her creating a risk of non-performance by Operator of its obligations under
this Agreement or otherwise creating a disruption.

               2.1.5 Maintain at the Facility accurate and up-to-date operating
logs and records regarding the operation and maintenance of the Facility, which
shall detail, among other things, power output, other operating data, repairs
performed and status of equipment as well as any information that may be
reasonably required by Owner.

               2.1.6 Implement and regularly update an equipment repair and
preventive maintenance program that meets the specifications of the equipment
manufacturers and operation and maintenance manuals.

               2.1.7 Act in accordance with Owner's or Owner's designated
experts' specific instructions (including but not limited to drilling programs
specifying Well location, casing to be used, depth to be drilled, drilling rig
standards, amount of materials required and standards for completion) with
respect to the geothermal and steam field and the drilling of new Wells, and
clean out, redrilling and reworking of existing Wells, and provide all technical
support and other services reasonable and necessary for operation and
maintenance of the Facility and the Wells.

               2.1.8 Provide reasonable safety and security measures for the
Facility and the Wells and the Facility's and Wells' sites, including any
necessary or desirable special safety gear for personnel.

               2.1.9 Recommend modifications, capital repairs, replacements and
improvements for the Steamboat Facility.

               2.1.10 Coordinate and implement all manufacturers' requirements
for plant equipment operation and diligently pursue warranty claims.

Steamboat Project O&M

                                       8

                          Operation and Maintenance Agreement - Steamboat Plants

               2.1.11 Endeavor to maintain good community relations.

               2.1.12 Produce plant data in the proper formats that are
necessary for reporting to any authorized US governmental authority for purposes
of obtaining and maintaining Authorizations, including regarding reporting
requirements under applicable environmental compliance Authorizations.

               2.1.13 Provide written Quarterly Operations Reports to Owner,
which include: (i) technical performance of the Steamboat Facility and the
Wells, including production, (ii) an accident incident report, (iii) safety and
environmental compliance status, (iv) equipment operational status, (v) a
summary of all major maintenance performed in the preceding quarter and that
planned for the coming quarter, including a summary of Major Corrective
Maintenance Work performed in the preceding quarter, and (vi) any other known
conditions which may adversely affect the technical or financial performance of
the Steamboat Facility and the Wells.

               2.1.14 Prepare and submit to Owner at least 60 (sixty) days prior
to the commencement of each Year of the Term, a proposed operating plan and
budget for the next Year.

                    The proposed operating plan and budget shall describe
anticipated Extraordinary Operation Expenses, including a monthly breakdown of
the same. The proposed operating plan and budget shall be subject to Owner's
review, comments and approval within 30 (thirty) days after receiving the
proposed plan and budget. Without limiting the foregoing, Owner shall have the
right to require changes to such proposed plan and budget only to the extent it
is not in accordance with prudent operating practice and manufacturers' and
systems' designers' specifications. Owner's approval or failure to approve the
proposed budget shall not derogate from Operator's obligations under this
Agreement.

                    If, upon the commencement of any Year any dispute of the
proposed plan and budget remains unresolved, a stand-by plan and budget in an
amount

Steamboat Project O&M

                                       9

                          Operation and Maintenance Agreement - Steamboat Plants

equivalent to the previous Year's plan and budget plus 3% (three percent) shall
be applied to the upcoming Year, pending resolution of the proposed dispute.
Upon resolution of the dispute, retroactive adjustments will be made to reflect
the implementation of the final plan and budget as of the beginning of the
relevant Year.

               2.1.15 Keep and maintain complete and accurate records of any
costs and expenses incurred (including in connection with the drilling of Wells)
which are to be reimbursed by Owner in accordance with sound and generally
accepted accounting principles consistently applied. Owner, at its cost and
expense, shall have access to all such records for examination, copying and
audit as reasonably requested from time to time.

               2.1.16 Accept the Geothermal Fluid supplied by Owner in
accordance with Section 3.1.7, and provide Injectate of the Facility to Owner at
the uppermost wellhead master flange of each injection Well.

               2.1.17 Except as otherwise provided herein, fulfill all
administrative functions and requirements in connection with running the
Steamboat Facility and the Wells including, without limitation, those required
under relevant law, the Power Purchase Agreements and the Associated Plant
Operating Agreements.

               2.1.18 Fully cooperate with Owner, Owner Affiliates and their
respective contractor(s) for their execution of planned works to enhance the
Steamboat Facility, such works to be executed in a manner as to minimize
stoppages and interruptions to the ongoing operation and maintenance of the
Steamboat Facility and the Wells, to the extent practicable.

     2.2  STANDARD OF CARE

          Operator shall perform the Work in a prudent and efficient manner and
in accordance with (i) prudent operating practice, including Owner instructions
of complying standard, (ii) manufacturers' and systems designers' specifications
and operation and

Steamboat Project O&M

                                       10

                          Operation and Maintenance Agreement - Steamboat Plants

maintenance manuals, (iii) Applicable Law in effect at the time of Operator's
performance, (iv) the relevant Authorizations, and (v) the requirements of the
Power Purchase Agreements, the Associated Plant Operating Agreements and this
Agreement. In addition, Operator shall perform the Work so as to (a) ensure that
the Facility and the Wells shall be kept in good condition, ordinary wear and
tear excepted, and (b) operate the Facility and the Wells in such a manner that
they shall comply with all safety and other requirements of insurance policies
in effect with respect to the Facility and the Wells. Operator shall use
reasonable and practical efforts (x) to maximize the Facility's energy and
capacity output, (y) to minimize the Facility's downtime, and (z) to keep in
full force and effect any warranties with respect to the Steamboat Facility.

     2.3  RESULTS OF OPERATOR NON COMPLIANCE

          If Owner directs Operator to correct Work due to non-compliance with
any of the standards set forth in Section 2.2 above, and Operator fails to
comply in a timely manner despite Owner notice and a reasonable cure period,
Owner shall be entitled to correct the noncompliance defect and offset the
reasonable, incurred direct cost from fees payable to Operator under this
Agreement.

     2.4  MAJOR CORRECTIVE MAINTENANCE WORK

          As soon as the need for Major Corrective Maintenance Work arises,
Operator shall submit to Owner a request to approve a Major Corrective
Maintenance Work. The request will provide Owner with details of the failure,
method of repair, cost estimate and time estimate of the repair work. Upon
approval of Owner, Operator will carry out the actions necessary to correct the
failure. Operator, at its own expense, shall make or cause to be made all
repairs caused by its gross negligence or willful misconduct or failure to
comply with its obligations under this Agreement.

          If Owner does not reply or raise reasonable objections to Operator's
request for a Major Corrective Maintenance Work within 10 (ten) days from the
time of the transmittal of such

Steamboat Project O&M

                                       11

                          Operation and Maintenance Agreement - Steamboat Plants

request, Operator shall perform such Major Corrective Maintenance Work as
Operator reasonably determines is necessary in accordance with prudent operating
practice, at Owner's expense as provided in Section 4.1.2.

          Notwithstanding the foregoing, the performance by Operator of Major
Corrective Maintenance Work, the cost of which is less than $10,000 (Ten
Thousand United States Dollars) per event, shall not require prior approval of
Owner.

     2.5  EMERGENCY MANAGEMENT POWERS

          Operator shall exercise emergency management powers in respect of any
aspect of the operation and maintenance of the Facility and the Wells to take
such action as a prudent operator or owner of the Facility and the Wells would
normally take in the circumstances (the "Emergency Management Powers"); and such
action shall not require prior approval of Owner, provided that (i) Operator
reasonably believes that immediate action is necessary to safeguard life or
property or to prevent or minimize an interruption in the production of electric
energy by the Facility or the performance of the Wells, and (ii) Operator is
unable due to events beyond its control or, acting reasonably, determines that
it is impractical to obtain Owner's prior written approval for the performance
of a Major Corrective Maintenance Work, as the case may be. Upon the exercise of
the Emergency Management Powers, Operator shall forthwith notify Owner in
writing of the nature of the Emergency Management Powers exercised by it, and
the reasons for exercising the Emergency Management Powers.

SECTION 3 - RESPONSIBILITIES AND RIGHTS OF OWNER

     3.1  OWNER'S RESPONSIBILITIES

          At all times throughout the Term, Owner shall be responsible for the
following activities, each to be at Owner's expense unless otherwise expressly
provided herein.

Steamboat Project O&M

                                       12

                          Operation and Maintenance Agreement - Steamboat Plants

          3.1.1 Make payments to Operator in accordance with Sections 4 and 5 of
this Agreement, and pay (or, as the case may be, reimburse Operator for) on a
timely basis, in addition to other costs and expenses payable or refundable by
Owner hereunder, (i) all utility costs payable to any person or entity,
including, without limitation, costs and fees associated with the supply of
demand charge services, purchase of electricity, wheeling, and scheduling of
electricity, and (ii) all costs and expenses in connection with obtaining,
renewing and keeping in force (a) the Authorizations and (b) the insurance
coverage contemplated in Section 11.1.1.3.

          3.1.2 Arrange for the sale of power generated by the Steamboat
Facility and for the billing and collection of revenues therefrom.

          3.1.3 Provide Operator free access to, and usage of, the Steamboat
Facility and the Wells on a continuing and uninterrupted basis and furnish such
offices, storage and maintenance facilities as are in Owner's possession at the
Effective Date and as may be subsequently acquired by Owner for this purpose
during the Term. Where necessary, office space at the Facility shall be provided
for Owner representative's use.

          3.1.4 Provide all drawings, specifications, diagrams and other
information Owner received from its consultants, suppliers or subcontractors or
which are otherwise in its possession now and in the future regarding the design
and construction of the Steamboat Facility and the Wells and all enhancement
works in connection therewith required for the operation and maintenance of the
Steamboat Facility and the Wells.

          3.1.5 Provide such assistance as Operator may reasonably require in
connection with obtaining, renewing and keeping in force the Authorizations.

          3.1.6 Maintain or cause its Affiliates to maintain in effect (and pay
on a timely basis all rents, royalties, costs, expenses and monies owing to the
Bureau of Land Management, the Minerals Management Service of the United States
Department of the Interior and/or any

Steamboat Project O&M

                                       13

                          Operation and Maintenance Agreement - Steamboat Plants

other person or entity, under or in connection with) all real property
ownership, geothermal leases (and subleases), site licenses, easements, rights
of way, rights to the geothermal reservoir, wells and fluid usage and
exploitation rights and associated project assets, including, without
limitation, the Leases, all as necessary for continuous operation of the
Steamboat Facility and the Wells, and provide or cause its Affiliates to provide
full, continuous and uninterrupted access and usage rights to Operator of the
same.

          3.1.7 Provide Operator all available Geothermal Fluid at the discharge
flange of the production pump of each geothermal production Well, and accept all
Injectate of the Steamboat Facility at the uppermost wellhead master flange of
each injection Well and reinject such Injectate in accordance with Applicable
Law.

          3.1.8 Supply, or arrange for the supply of, demand charge services,
electricity, wheeling and services for the scheduling of electricity throughout
the Term, as required by Operator for the performance of its obligations
hereunder.

          3.1.9 Review in accordance with the periods specified herein, and if
not specified, in a timely fashion, and not unreasonably withhold its approval
of all items submitted by Operator to Owner for approval.

          3.1.10 Owner shall be responsible to ensure that all transmission
facilities for the Steamboat Facility are maintained for the interconnection of
the Steamboat Facility at the points of interconnection, and the provision of
firm transmission services to the Facility is maintained, all throughout the
Term so that they will be sufficient for the testing and operation of the
Steamboat Facility, as required under the Power Purchase Agreements.

          3.1.11 Provide Operator with the tools, equipment, vehicles, initial
stock of spare parts, consumables and other items available on the date hereof.

          3.1.12 Designate an Owner representative who shall act as a single
point of

Steamboat Project O&M

                                       14

                          Operation and Maintenance Agreement - Steamboat Plants

contact with Operator in all matters in respect of this Agreement on behalf of
Owner. Owner shall, or shall cause its designated expert to, issue specific
instructions (which at Operator's request, shall be in writing) with respect to
the geothermal and steam field associated with the Steamboat Facility, including
with regard to the drilling of new Wells, and clean out, redrilling and
reworking of existing Wells.

          3.1.13 Diligently enforce and refrain from waiver of any of its rights
under the Power Purchase Agreements and the Associated Plant Operating
Agreements, and diligently pursue any claims to which it is entitled under such
agreements.

          3.1.14 Owner shall perform and shall ensure that its contractors and
subcontractors perform all of their works at the Steamboat Facility and Wells
sites, in such a manner as to minimize any interference with the Operator's
activities hereunder.

          3.1.15 Pay on a timely basis all costs, fees, expenses and monies
owing to real property owners or leaseholders, the Bureau of Land Management of
the United States Department of the Interior, the Minerals Management Service of
the United States Department of the Interior and/or any other authorized
governmental authority or private entity, under or in connection with any
agreements, bonds, sureties and/or guarantees of Owner.

     3.2  RESULTS OF OWNER NON COMPLIANCE UNDER SECTION 3.1

          If Owner does not completely perform any or all of its obligations
described in Section 3.1 above, in addition to any other payments owed under
this Agreement, Operator shall be entitled to the payment by Owner to it of all
Operator's reasonable additional costs and expenses as well as any extension of
time reasonably required by Operator under this Agreement as a result of such
failure to fully perform by Owner (or its representatives, other subcontractors
or suppliers).

     3.3  APPROVAL OF OPERATOR'S PLANTS MANAGER AND REPLACEMENT OF OWNER'S

Steamboat Project O&M

                                       15

                          Operation and Maintenance Agreement - Steamboat Plants

          REPRESENTATIVE

          Owner shall have the right to approve the Plants Manager designated or
replaced by Operator. Such approval will not be unjustifiably withheld. Owner
shall have the right to require Operator to replace the Plants Manager, upon
reasonable notice. All costs associated with the replacement of the Plants
Manager shall be at Owner's account, unless replaced for justifiable cause.

SECTION 4 - PAYMENTS

     4.1  PAYMENT OBLIGATIONS

          In addition to other payment obligations provided in this Agreement,
Owner shall be responsible for all of the following main payment obligations:
Operation Fee and Extraordinary Operation Expenses.

          4.1.1 OPERATION FEE

               Commencing on the day of execution of this Agreement and
throughout the Term, Owner shall pay to Operator a fixed monthly fee of $246,250
(Two Hundred and Forty Six Thousand Two Hundred and Fifty USD), subject to
adjustment based on the Consumer Price Index, Urban Consumers - West (CPI-U,
West) on January 1 of each Year, which shall cover all costs associated with the
ordinary maintenance of the Steamboat Facility (the "Operation Fee"). The
Operation Fee shall include, but not be limited to, the cost of labor, parts,
consumables and fees and costs of subcontractors, provided, however, that the
payment of the above fee shall not cover and shall be in addition to additional
payments to Operator and costs at Owner's additional expense with regard to: (a)
Extraordinary Operation Expenses, (b) costs and expenses caused to Operator as a
result of Owner non-compliance with any of its obligations described in Sections
3 or 7, (c) all costs and expenses of Owner in connection with the performance
of any of its

Steamboat Project O&M

                                       16

                          Operation and Maintenance Agreement - Steamboat Plants

obligations under this Agreement, (d) all Operator costs and losses for which
Owner is responsible under Section 3.2, and (e) any other costs, reimbursement
obligations, expenses, losses, or damages and any taxes, duties, levies or fees
which are expressly described in this Agreement as an Owner obligation
(including, without limitation, those described in Section 3.1.1), all of which
shall be at Owner's additional expense. At Operator's written request, the
Parties shall renegotiate in good faith the Operation Fee for every 5 (five)
year period, so as to reflect as nearly as possible the economic factors that
were the basis for the calculation of the initial Operation Fee and other
factors and circumstances justifying the adjustment of the same. If Owner does
not accept Operator's proposal for adjustment of the Operation Fee within 15
(fifteen) days of the date of such request, Operator shall be entitled to
terminate this Agreement upon written notice to Owner, and the results of such
termination shall be as described in Section 8.4.

          4.1.2 EXTRAORDINARY OPERATION EXPENSES

               Owner shall reimburse Operator the actual cost and expenses plus
a 10% (ten percent) mark-up for the following items:

                    A. All Major Corrective Maintenance Work to the Steamboat
Facility (labor, parts and materials).

                    B. Any modification, addition or deletion to the Steamboat
Facility equipment (other than routine replacement of parts and consumables)
performed with prior approval by the Owner, and which was not a result of
Operator gross negligence, willful misconduct, or Operator failure to comply
with its obligations under this Agreement.

                    C. Any cost incurred as a result of any change in Applicable
Law enacted or promulgated after the Effective Date, other than with respect to
taxes described in Section 4.1.3(i)(A); any change in the Authorizations after
the Effective Date; change to the Power Purchase Agreements or the Associated
Plant Operating Agreements after the Effective

Steamboat Project O&M

                                       17

                          Operation and Maintenance Agreement - Steamboat Plants

Date; or in its exercise of Emergency Management Powers which was not a result
of Operator gross negligence, willful misconduct, or Operator failure to comply
with its obligations under this Agreement.

                    D. Any cost caused to Operator with respect to environmental
responsibilities of Owner under Section 7.1 hereto.

                    E. Works in connection with the Wells, including, without
limitation, labor, materials, supplies, consumables, technical, professional and
other services associated with production pumps and motors and chemicals used
for Wells and pump scale inhibitors, and clean out, redrilling, reworking and
drilling of new Wells to be performed under Owner's or Owner designated expert's
specific instructions (including drilling programs specifying well location,
casing to be used, depth to be drilled, drilling rig standards, amount of
materials required and standards for completion), to be issued in writing at
Operator's request. Notwithstanding anything to the contrary herein, Operator
shall have no liability for the effect of such works on the production
capability of the Steamboat Facility, the geothermal reservoir, the Wells or the
composition of the Geothermal Fluid, and Owner shall be exclusively responsible
and liable for the results of Owner's or Owner designated expert's specific
instructions in connection with clean out, redrilling, reworking and drilling of
new Wells.

          4.1.3 TAXES

               (i) Operator shall be liable for, and shall not receive any
payment from Owner in excess of Owner's other payment obligations hereunder in
connection with (A) any taxes imposed on Operator or its subcontractors with
respect to or based upon the net income, revenues or profits of Operator or its
subcontractors (other than sales or use tax, if applicable, for which tax Owner
is responsible under this Agreement), (B) any taxes or contributions in the
nature of workman's compensation or social security benefits based upon or
relating to the employment of workers by Operator or any subcontractor, and (C)
any US sales, use, excise, value added, goods and services tax, and US import
duties, customs duties and port lease

Steamboat Project O&M

                                       18

                          Operation and Maintenance Agreement - Steamboat Plants

expenses, if any, with respect to services, equipment, goods and materials which
Operator acquires or imports in connection with those items included in and
covered by the Operation Fee.

               (ii) Owner shall be liable for, and in addition to its other
payment obligations under this Agreement, shall pay (or in the case of (C)
below, reimburse Operator, where applicable) (A) any US real estate taxes or
other US ad valorem, ownership or property related taxes on the Steamboat
Facility and Wells sites, (B) any taxes imposed on Owner or its contractors or
subcontractors (other than Operator and Operator's subcontractors) with respect
to or based upon the net income, revenues or profits of Owner or such other
contractor or subcontractors, (C) any US sales, use, excise, value added, and
goods and services tax, if any, in connection with or in respect of any amount
payable to Operator under this Agreement, and (D) any US withholding tax, sales,
use, excise, value added, goods and services tax, and US import duties, customs
duties and port lease expenses, if any, assessed in connection with any item
acquired or imported with respect to the Facility, unless such tax, duty,
expense or contribution is expressly described as an Operator obligation under
clause (i)(C) above.

               (iii) Owner shall promptly reimburse Operator upon demand for all
amounts actually paid by Operator for which Owner is liable pursuant to clause
(ii) above. Without limiting Owner's reimbursement obligation in the foregoing
sentence, Operator shall administer and pay all taxes, duties and contributions
described in clause (ii) imposed by any taxing authority, and shall furnish to
the appropriate taxing authorities all required information and reports in
connection with such taxes, duties and contributions and promptly furnish copies
of all such information and reports to Owner. Owner shall use all reasonable
efforts to cause its general manager and administrative management team to
cooperate fully with Operator in connection with the matters described in this
clause (iii).

SECTION 5 - BILLING

     5.1 Within 15 (fifteen) days of the end of each month, Operator shall
submit an

Steamboat Project O&M

                                       19

                          Operation and Maintenance Agreement - Steamboat Plants

Operator's Invoice to Owner. Each Operator's Invoice shall contain a statement
of all amounts due to Operator for the Operation Fee, for all Extraordinary
Operation Expenses incurred during the previous month, and for any other fees,
costs or expenses owed by Owner to Operator under this Agreement. Payment of the
Operator's Invoice shall be due 15 (fifteen) days after the receipt by Owner of
said invoice.

     5.2 In the event that Owner disputes the amount of an Operator's Invoice,
Owner shall render payment for the undisputed portion of such Operator's Invoice
when such payment would otherwise be due under this Section 5. In the event that
Owner fails to pay the Invoice in full within the period described in Section
5.1 above, and any portion of disputed amounts are determined to be due and
owing to Operator, without derogating from Operator's other rights under this
Agreement or under law, Owner shall pay to Operator, in addition to such unpaid
or disputed amounts, interest for amounts determined to be owed at a rate per
annum equal to the Prime Rate plus 2 1/2% (two and one half percent) from the
date such amounts were due until paid in full. With respect to disputed invoiced
amounts or payments, the Party disputing either the Operator's Invoice or the
payment of any such amount shall notify in writing the other Party within 7
(seven) days of receipt of the disputed Operator's Invoice or payment stating
the reason for such dispute and such dispute shall be settled by the respective
representatives of the Parties within 60 (sixty) days from the date of the
notice or as provided in Section 15.1.

     5.3 Each monthly invoice shall, in its accounting of the previous month's
Extraordinary Operation Expenses incurred, set forth the description, price and
quantity of goods, property or services delivered or rendered. Operator's
Invoices shall be delivered to Owner at the address specified in Section 15.7.

          All payments due to Operator in response to written invoices presented
by the Operator shall be paid in United States Dollars. Payment shall be made by
wire transfer in immediately available funds on or before the date due to the
bank account whose details shall be determined by Operator and notified to
Owner.

Steamboat Project O&M

                                       20

                          Operation and Maintenance Agreement - Steamboat Plants

SECTION 6 - FORCE MAJEURE

     6.1 No failure or omission to carry out or observe any of the terms,
provisions, or conditions of this Agreement (other than the obligation to pay
money) shall give rise to any claim by any Party against any other Party hereto,
or be deemed to be a breach or default of this Agreement if the same shall be
caused by or arise out of any event or circumstances beyond the reasonable
control (directly or indirectly) of the Party whose performance Force Majeure
has affected including, but not limited to, any war, declared or not, invasion,
armed conflict or act of foreign enemy, blockade, embargo, revolution,
insurrection, riot, civil commotion, act of terrorism, or sabotage provided that
any such event occurs within or directly involves the US or any other country
from which machinery, equipment and material for the Facility and/or the Wells
are procured or transported through, an act of God, including but not limited to
lightning, fire, earthquakes, volcanic activity, floods, storms, cyclones,
typhoons, or tornadoes, epidemics or plagues, explosions or chemical
contamination (other than resulting from an act of war), labor disputes
including strikes, or go-slows or lockouts that extend beyond the Steamboat
Facility and/or the Wells or are widespread or nationwide, change in Applicable
Law, or any other event, matter or thing, wherever occurring, to the extent that
such event or circumstances or its effects cannot be prevented, avoided or
removed by such Party while exercising that degree of skill, diligence, prudence
and foresight which could reasonably be expected from the Party affected thereby
in the same of similar circumstances, each of the foregoing events, matters or
things being called "Force Majeure" in this Agreement.

     6.2 If either Party has been rendered wholly or partly unable to perform
its obligations, (other than the obligation to make payments) because of an
event of Force Majeure, the affected Party shall be excused from performance of
its obligations to the extent that such performance is prevented by the Force
Majeure, and shall consult with the other Party with respect to its plans to
mitigate or limit the effect of such event, and shall take such actions as are
reasonable under the circumstances.

     6.3 If an event of Force Majeure continues for a period of more than 180
(one

Steamboat Project O&M

                                       21

                          Operation and Maintenance Agreement - Steamboat Plants

hundred eighty) days, Owner may terminate this Agreement by providing 30
(thirty) days written notice of such termination to Operator; provided that such
30 (thirty) day notice period shall run concurrently with such 180 (one hundred
eighty) day period. The results of such termination shall be as described in
Section 8.4.

SECTION 7 - ENVIRONMENTAL RESPONSIBILITIES

     7.1  ENVIRONMENTAL RESPONSIBILITIES OF OWNER

          In addition to its other payment obligations under this Agreement,
Owner shall be responsible for all costs (including, without limitation,
penalties) associated with any clean-up, removal, response or remediation of any
and all contamination required under Applicable Law, except to the extent such
contamination arises out of or results from the gross negligence or willful
misconduct of Operator or any of its subcontractors, vendors, representatives,
agents or employees in the performance of Operator's obligations hereunder.

          Owner shall, in accordance with the procedures in Section 9.3,
indemnify and hold harmless Operator, its officers, employees, agents,
contractors, vendors representatives and Affiliates, from and against any and
all Damages (as that term is defined in Section 9.1) arising out of or resulting
from (a) any matter for which Owner is responsible pursuant to this Section 7,
or (b) any contamination occurring on or off the Facility or Wells sites
attributable to any materials that arise out of, result from or relate to (i)
the use or occupancy of, or entry or re-entry on, the Facility or the Wells or
the Facility or Wells sites (whether before, during or after the Term of this
Agreement) by Owner, and its respective officers, employees, agents,
contractors, vendors, or representatives (other than Operator and its
contractors, vendors, representatives and employees), (ii) any other acts or
omissions of Owner, and its respective officers, employees, agents, contractors,
vendors, or representatives (other than Operator and its contractors, vendors,
representatives and employees), at the Facility or the Wells or the Facility or
Wells sites, other than gross negligence or willful misconduct of Operator or of
any of its subcontractors, vendors,

Steamboat Project O&M

                                       22

                          Operation and Maintenance Agreement - Steamboat Plants

representatives, agents or employees.

     7.2  ENVIRONMENTAL RESPONSIBILITIES OF OPERATOR

          Operator shall be responsible for the clean-up of, and all costs
associated with the removal, response or remediation of, any and all
contamination to the extent that such contamination arises out of or results
from the gross negligence or willful misconduct of Operator or any of its
subcontractors, vendors, representatives, agents or employees in the performance
of Operator's obligations hereunder.

          Operator shall, in accordance with the procedures in Section 9.3,
indemnify and hold harmless Owner, its officers, employees, agents, contractors,
vendors, representatives, and Lenders, from and against any and all Damages (as
that term is defined in Section 9.1) arising out of, resulting from any matter
for which Operator is responsible pursuant to this Section 7.2.

     7.3  NOTICE OF REMEDIATION: TERMINATION

          7.3.1 If Operator discovers contamination or any other condition of
the Facility or the Wells that (a) violates or could result in a violation of
any material relevant environmental provision of Applicable Law, or (b) is the
responsibility of Owner under Section 7.1, Operator shall promptly notify Owner
thereof.

               (i) Upon receipt of a notice pursuant to Section 7.3.1, Owner
shall commence and diligently prosecute remediation of the Facility and the
Wells and the Facility and Wells sites to the extent necessary to enable
operations to resume or continue and to correct all violations of Applicable
Law.

               (ii) To avoid any doubt, any remediation hereunder shall be at
Owner's sole cost and expense, unless Operator's or any of its subcontractors,
vendors, representatives, agents or employees' gross negligence or willful
misconduct was the cause of the condition

Steamboat Project O&M

                                       23

                          Operation and Maintenance Agreement - Steamboat Plants

requiring remediation.

          7.3.2 If Operator discovers contamination or any other violation of
any relevant environmental provision of Applicable Law at or associated with the
Facility or the Wells that could in any way impede, burden or adversely affect
Operator's operation or maintenance of the Facility or the Wells or that
increases the cost of such operation or maintenance, such increase shall be
included as an Extraordinary Operation Expense, except to the extent such
condition was caused by the gross negligence or willful misconduct of Operator
or any of its subcontractors, vendors, representatives, agents or employees.

SECTION 8 - TERM AND TERMINATION

     8.1  TERM

          This Agreement will be binding upon the Parties on the Effective Date,
and shall remain binding until the expiration or termination of all of the Power
Purchase Agreements, unless terminated earlier in accordance with Section 6.3 or
this Section 8.

     8.2  TERMINATION BY OWNER

          8.2.1 Owner may terminate this Agreement prior to the expiration of
its Term in any of the following circumstances with prior written notice,
provided, however, that the notice and cure period shall be (a) 30 (thirty) days
in the case of a failure by Operator to perform any material obligation
hereunder, unless Operator has cured such failure during the notice period or
has initiated and is diligently pursuing the cure of such breach and thereafter
continues to diligently pursue such cure and such cure is effected within 180
(one hundred eighty) days from the receipt of such notice by Operator, and (b)
no prior notice shall be required in the case of termination due to the
Bankruptcy, insolvency or dissolution of Operator.

Steamboat Project O&M

                                       24

                          Operation and Maintenance Agreement - Steamboat Plants

          8.2.2 If specifically requested by Owner, Operator shall use all
reasonable efforts to continue performing its obligations under this Agreement
upon termination by Owner through the applicable notice and cure period
described in Section 8.2.1 above. Owner will continue to reimburse and
compensate Operator for the Operation Fee and Extraordinary Operation Expenses
in accordance with this Agreement to the extent Operator continues to perform.
In addition, at Owner's specific request, Operator shall assign any and all
subcontracts it has entered into relating to the Work and whose provisions
permit such assignment to Owner upon termination by Owner in accordance with
Section 8.2.1.

          8.2.3 If the Operator ceases all or a substantial part of the
operations and maintenance activities at the Steamboat Facility for more than 10
(ten) consecutive days for any reason, and Owner or another operator is capable
of properly conducting operation and maintenance activities in accordance with
the requirements set forth in Section 2.2 of this Agreement, Owner may, at its
own risk, perform or cause the performance of such operation and maintenance of
the Steamboat Facility until such time as Operator is able to reliably resume
the operation and maintenance of the Steamboat Facility. All costs incurred by
Owner in temporarily conducting the operation and maintenance as aforesaid may
be offset against any amounts due to Operator, provided, however that where
Operator cessation of activities is due to Force Majeure or Owner
non-performance of any of its obligations hereunder, Owner shall bear such
costs.

     8.3  TERMINATION BY OPERATOR

          Operator may terminate this Agreement prior to the expiration of its
Term in any of the following circumstances:

          8.3.1 Upon the Bankruptcy, insolvency or dissolution of Owner;

          8.3.2 Upon written notice to Owner if there is a failure by Owner to
pay when due any amounts owed to Operator.

Steamboat Project O&M

                                       25

                          Operation and Maintenance Agreement - Steamboat Plants

          8.3.3 Upon 30 (thirty) days written notice to Owner if there is a
failure or a delay by Owner to completely perform any or all of its obligations
under Section 3.1 and such failure(s) or delay(s) render it impossible or highly
impractical for Owner to perform its obligations hereunder for 180 (one hundred
eighty) days in the aggregate, unless Owner has cured such breach during the
notice period.

          8.3.4 Upon written notice to Owner, as provided in Section 4.1.1
hereof.

     8.4  RESULTS OF TERMINATION

          In the case of termination pursuant to Sections 6.3 or 8.3, Owner
shall pay Operator (i) the Operation Fee due and all Extraordinary Operation
Expenses accrued by Operator as well as all other sums due as of the date of the
termination, and (ii) any reasonable costs attributable to termination of this
Agreement, including without limitation, costs of demobilization and
cancellation charges owed to third parties.

          In the case of termination pursuant to Section 8.2, Owner will pay
Operator the amounts described in clause (i) above, and Owner shall not be
obligated to pay the amounts described in clause (ii) above or any other
termination fee or other compensation. Except to the extent that obligations by
their terms expressly survive termination, or arose prior to the date of
termination, or as a result of termination, or as provided in the preceding
sentence, neither party shall have any additional liability to the other as a
result of or following termination.

SECTION 9 - INDEMNIFICATION

     9.1  INDEMNITY BY OPERATOR

          Operator shall fully indemnify, save harmless and defend Owner,
Lenders, each of

Steamboat Project O&M

                                       26

                          Operation and Maintenance Agreement - Steamboat Plants

their subsidiaries and Affiliates, and the directors, officers, shareholders,
agents, employees, successors and assigns of each of them (the "Owner
Indemnified Parties"), from and against any and all liability arising from third
party claims, suits, losses, costs, damages, injuries, liabilities, demands,
penalties, interest and causes of action, including without limitation
reasonable attorney's fees, (collectively, the "Damages"), arising out of,
resulting from, or related to this Agreement, including without limitation any
damage to or destruction of property, or death of or bodily injury to, any
person (whether they are employees of the Owner Indemnified Parties, Operator or
any subcontractor, or are persons unaffiliated with the Facility and/or the
Wells) to the extent caused by Operator's gross negligence or willful
misconduct, if the claim or cause of action has arisen prior to the termination,
expiration or completion of this Agreement or within 3 (three) years thereafter.
It is expressly agreed that where the Owner Indemnified Parties are
contributorily negligent, such contributory negligence will not preclude
recovery under the preceding sentence, but Operator's indemnity will not include
Damages to the extent caused by such contributory negligence. Operator's
aforesaid indemnity is for the exclusive benefit of the Owner Indemnified
Parties and in no event shall inure to the benefit of any other party.

     9.2  INDEMNITY BY OWNER

          Owner shall fully indemnify, save harmless and defend Operator, its
subcontractors, each of their subsidiaries and Affiliates, and the directors,
officers, shareholders, agents, employees, successors and assigns of each of
them (the "Operator Indemnified Parties"), from and against any and all Damages,
arising out of, resulting from, or related to this Agreement, including without
limitation any damage to or destruction of property of, or death of or bodily
injury to, any person (whether they are employees of the Operator Indemnified
Parties, Operator or any subcontractor, or are persons unaffiliated with the
Facility and/or the Wells) to the extent the Damages are not included in the
Operator indemnification obligation under Section 9.1 above, if the claim or
cause of action has arisen prior to the termination, expiration or completion of
this Agreement or within 3 (three) years thereafter. It is expressly agreed that
where the Operator Indemnified Parties are contributorily grossly negligent,
such contributory gross negligence will not preclude recovery under the
preceding sentence, but Owner's indemnity

Steamboat Project O&M

                                       27

                          Operation and Maintenance Agreement - Steamboat Plants

will not include Damages to the extent caused by such contributory gross
negligence. Owner's aforesaid indemnity is for the exclusive benefit of the
Operator Indemnified Parties and in no event shall inure to the benefit of any
other party.

     9.3  INDEMNITEE NOTICE

          The party seeking indemnity is hereinafter referred to as the
"Indemnitee" and the party against whom indemnity is sought is hereinafter
referred to as the "Indemnitor". An Indemnitee shall, within 10 (ten) business
days of the receipt of notice of the commencement of any legal action or of any
claims against such Indemnitee in respect of which indemnification will be
sought, notify Indemnitor in writing thereof. Failure of the Indemnitee to give
such notice will reduce the liability of Indemnitor by the amount of damages
attributable to the failure of the Indemnitee to give such notice to Indemnitor
but the failure to so notify shall not relieve Indemnitor from any liability
which it may have to such Indemnitee under the indemnity agreements contained in
this Section 9 or otherwise. In case any such claim or legal action shall be
made or brought against an Indemnitee and such Indemnitee shall notify
Indemnitor thereof, Indemnitor may, or if so requested by such Indemnitee shall,
assume the defense thereof, with a reservation of rights, with counsel
reasonably satisfactory to such Indemnitee, and after notice from Indemnitor to
such Indemnitee of an election to assume the defense thereof and approval by the
Indemnitee of such counsel, will not be liable to such Indemnitee under this
Section 9 for any legal fees and expenses subsequently incurred by such
Indemnitee in connection with the defense thereof. No Indemnitee shall settle
any indemnified claim over which Indemnitor has not been afforded the
opportunity to assume the defense without Indemnitor's approval, which approval
shall not be unreasonably withheld. Indemnitor shall control the settlement of
all claims over which it has assumed the defense; provided, however, that
Indemnitor shall not conclude any settlement which requires any action or
forbearance from action by Indemnitee or any of its Affiliates without the prior
approval of Indemnitee. The Indemnitee shall provide reasonable assistance to
Indemnitor at Indemnitor's expense in connection with such legal action or
claim. If Indemnitor shall not have employed counsel to conduct the defense of
any such claim or action within a reasonable time after notice of assertion of
such claim or of commencement of such

Steamboat Project O&M

                                       28

                          Operation and Maintenance Agreement - Steamboat Plants

action, legal and other expenses, including the expenses of separate counsel,
incurred by such Indemnitee shall be borne by Indemnitor. In all cases the
Indemnitee shall have the right to participate in and be represented by counsel
of its own choice and at its own expense in any such legal action or with
respect to any claim and the Indemnitee shall have the right to be represented
by separate counsel at the expense of the Indemnitor if the named parties to
such action include both such Indemnitee and the Indemnitor and the claims or
defenses which Indemnitee chooses to assert are conflicting or inconsistent with
the claims or defenses that Indemnitor chooses to assert.

     9.4  EMPLOYEES

          Neither Party nor its directors, officers, employees, agents,
Affiliates or representatives, nor any independent subcontractors engaged by it
in connection with the performance of this Agreement, shall be deemed an
employee of the other Party. Neither Party shall bring any claim against the
other Party or its directors, officers, Affiliates, agent, representatives,
employees or independent subcontractors with respect to any liability for
compensation under an applicable statue or any applicable governmental rule for
Worker's Compensation, if applicable, and/or employer's liability claims of
employees.

     9.5  NET AMOUNT

          In the event that an Indemnifying Party is obligated to indemnify and
hold any Indemnified Party harmless under this Section, the amount owing to the
Indemnified Party shall be the amount of such indemnified Party's actual
out-of-pocket loss, net of any insurance or other recovery.

SECTION 10 - LIMITATION OF LIABILITY

Steamboat Project O&M

                                       29

                          Operation and Maintenance Agreement - Steamboat Plants

          10.1 In no event shall either Party be liable for indirect, special,
consequential, exemplary or incidental damages, nor for loss of anticipated
profits or revenues or for loss or use of any equipment, installation system,
operation or service into which goods or parts may be put, or with respect to
which any Work may be performed by Operator, cost of capital, cost of substitute
equipment, facilities, services or replacement power, downtime cost or claims of
Owner's customers regardless of form of action, whether as a result of breach of
contract, warranty, guarantee, indemnity, or tort, including negligence and
strict liability. This limitation on liability shall apply to any liability for
default under or in connection with the goods, parts or services delivered
hereunder, whether based on warranty, failure of, or delay in delivery or
otherwise.

          10.2 In no event shall Operator's aggregate liability under, in
connection with or arising from, this Agreement, whether regarding any
indemnification, environmental responsibility or otherwise, exceed the sum of
$2,000,000 (Two Million United States Dollars).

SECTION 11 - INSURANCE

     11.1 OPERATOR'S COVERAGES

          11.1.1 Operator shall provide or obtain and maintain in force through
the term of this Agreement, the following insurance coverages:

               11.1.1.1 WORKMEN'S COMPENSATION

                    At Operator's cost and expense, workmen's compensation
insurance, disability benefit and other similar employee benefit acts in amounts
required by Applicable Law, at Operator's cost and expense.

Steamboat Project O&M

                                       30

                          Operation and Maintenance Agreement - Steamboat Plants

               11.1.1.2 AUTOMOBILE LIABILITY

                    At Operator's cost and expense, automobile liability
insurance covering bodily injury and property damage, for hired, owned and
non-owned vehicles.

               11.1.1.3 COMPREHENSIVE GENERAL LIABILITY

                    At Owner's cost and expense, comprehensive general liability
insurance covering personal injury (including bodily injury and death) and
property damage to third parties and covering liability for damage to property
of third parties in the care, custody and control of Owner, Operator and/or
their respective employees in connection with operations at the Steamboat
Facility and the Wells with a combined single limit of not less than $1,000,000
(One Million USD) per occurrence and $5,000,000 (Five Million USD) annual
aggregate for bodily injury and property damage.

          11.1.2 Owner shall be listed as an additional insured on all policies
listed in Section 11.1.1 above, and such policy provisions shall provide that
Owner be given 60 (sixty) days (10 (ten) days in the case of non-payment of
premiums) written notice from the insurance company of policy cancellation(s),
modifications or terminations.

          11.1.3 The obligation to carry the insurance required by this Section
11.1 shall not limit or modify in any way other obligations assumed by Operator
under this Agreement. Owner shall not be under any duty to examine policies,
certificates or other evidence of Operator's insurance, or to advise Operator in
the event that Operator's insurance is not in compliance with this Agreement.

     11.2 INDEPENDENT CONTRACTOR'S COVERAGE

          Each of the Parties shall require all of its independent consultants,
contractors and subcontractors to obtain, maintain and keep in force during the
time in which they are engaged in

Steamboat Project O&M

                                       31

                          Operation and Maintenance Agreement - Steamboat Plants

performing services in connection with the Steamboat Facility and the Wells
reasonably adequate insurance coverage in accordance with prudent industry
practice and reasonably acceptable to the other Party and furnish such other
Party with acceptable evidence of such insurance upon its request. Neither Party
shall have responsibility for payment of premiums and claims with respect to the
insurance of the other Party's independent consultants, contractors and
subcontractors.

     11.4 CERTIFICATES: PROOF OF INSURANCE

          On or before the required date for the insurance to be provided
hereunder, each Party shall furnish certificates of insurance to the other Party
evidencing the insurance required of such Party pursuant to this Agreement.

SECTION 12 - ASSIGNMENT

     12.1 ASSIGNMENT BY OPERATOR

          This Agreement may not be assigned by Operator without the prior
written consent of Owner, and such consent shall not be unreasonably withheld or
delayed. In the case of assignment to an Affiliate of Operator, such consent
shall not be required.

     12.2 ASSIGNMENT BY OWNER

          This Agreement may not be assigned by Owner without the prior written
consent of Operator, which consent shall not be unreasonably withheld or
delayed; provided, however, that Owner may collaterally assign its rights under
this Agreement to the Lender(s) without Operator's prior consent. Operator
agrees to execute a consent to such assignment and such other documents as may
reasonably be requested by Owner and the Lender(s) in connection with such

Steamboat Project O&M

                                       32

                          Operation and Maintenance Agreement - Steamboat Plants

assignment. Operator further agrees that such consent to assignment will contain
a requirement to provide notice to the Lenders and to permit reasonable cure
periods on the part of the Lenders for Owner default under this Agreement.

SECTION 13 - REPRESENTATIONS, WARRANTIES AND COVENANTS

     13.1 REPRESENTATIONS BY OPERATOR

          Operator represents and warrants to Owner as follows:

          13.1.1 ORGANIZATION

               Operator is a corporation duly established, validly existing and
in good standing under the laws of the State of Delaware, and the execution,
delivery and performance of this Agreement has been duly authorized by all
necessary action and will not violate any provisions of any Applicable Law, its
organizational documents, or any indenture, agreement or instrument to which it
is party or by which it or any of its property may be bound or affected. This
Agreement has been duly executed and delivered by Operator and constitutes a
legal, valid and binding obligation of Operator, enforceable in accordance with
its terms, except as such enforceability may be limited by bankruptcy,
insolvency, or other similar laws affecting the enforcement of creditors' rights
generally, from time to time in effect, and by general principles of equity
(regardless of whether such enforceability is considered in a proceeding in
equity or at law).

          13.1.2 NO VIOLATION OF LAW

               Operator is not in violation of any Applicable Law including,
without limitation, the U.S. Foreign Corrupt Practices Act, or of a judgment
entered by any governmental authority, which violations, individually or in the
aggregate, would affect Operator's performance

Steamboat Project O&M

                                       33

                          Operation and Maintenance Agreement - Steamboat Plants

of its obligations under this Agreement.

          13.1.3 LITIGATION

               Operator is not a party to any legal, administrative, arbitral,
investigatorial or other proceeding or controversy pending, or, to the best of
Operator's knowledge, threatened, that would adversely affect Operator's ability
to perform under this Agreement.

          13.1.4 QUALIFICATIONS

               Operator has: (i) examined the Power Purchase Agreements, the
Associated Plant Operating Agreements and this Agreement thoroughly and become
familiar with their terms; (ii) proper qualifications to perform the Work
hereunder; and (iii) carefully reviewed all documents, plans, drawings and other
information, including Applicable Law, that it deems necessary regarding the
Steamboat Facility and the Wells and its performance of the Work hereunder that
are available as of the date hereof.

          13.1.5 ACCEPTANCE OF THE FACILITY

               Operator acknowledges that it has become familiar with the
proposed components and characteristics of the Facility and the Wells to the
extent deemed necessary by it, and that, in its opinion the components and
characteristics of the Facility and the Wells are sufficient for the performance
of its obligations hereunder.

     13.2 REPRESENTATIONS BY OWNER

               With respect to itself, each single entity comprising Owner
represents and warrants to Operator as follows:

               13.2.1 ORGANIZATION

Steamboat Project O&M

                                       34

                          Operation and Maintenance Agreement - Steamboat Plants

               It is a limited liability company duly organized, validly
existing and in good standing under the laws of the State of Delaware, and the
execution, delivery and performance of this Agreement has been duly authorized
by all necessary action and will not violate any provisions of any Applicable
Law, its organizational documents, or any indenture, agreement or instrument to
which it is party or by which it or any of its property may be bound or
affected. This Agreement has been duly executed and delivered by it, and
constitutes a legal, valid and binding obligation of itself, enforceable in
accordance with its terms, except as such enforceability may be limited by
bankruptcy, insolvency, or other similar laws affecting the enforcement of
creditors' rights generally, from time to time in effect, and by general
principles of equity (regardless of whether such enforceability is considered a
proceeding in equity or at law).

          13.2.2 NO VIOLATION OF LAW

               It is not in violation of any Applicable Law, including, without
limitation, the U.S. Foreign Corrupt Practices Act or of a judgment entered by
any governmental authority, which violations, individually or in the aggregate,
would affect its performance of its obligations under this Agreement.

          13.2.3 LITIGATION

               It is not a party to any legal, administrative, arbitral,
investigatorial or other proceeding or controversy pending, or, to the best of
its knowledge, threatened, that would adversely affect its ability to perform
under this Agreement.

SECTION 14 - SUBCONTRACTORS

     Operator may enter into subcontracts for the performance of the Work and
shall be solely responsible for the management and satisfactory performance of
all of its subcontractors. The

Steamboat Project O&M

                                       35

                          Operation and Maintenance Agreement - Steamboat Plants

issuance of any subcontract shall not relieve Operator from any of its
obligations under this Agreement.

     Owner will have the right to require Operator to remove or replace any
subcontractor whose performance is disrupting or is likely to disrupt proper
operation of the Facility or the Wells.

SECTION 15 - MISCELLANEOUS

     15.1 DISPUTE RESOLUTION

          The competent courts of the State of Nevada, shall have exclusive
jurisdiction with respect to any and all disputes arising out of or in
connection with this Agreement.

     15.2 INDEPENDENT CONTRACTOR

          Except as otherwise provided herein Operator shall at all times be
deemed an independent contractor.

     15.3 SEVERABILITY

          The invalidity, in whole or in part, of any of the foregoing Sections
or paragraphs of this Agreement will not affect the validity of the remainder of
such Sections or paragraphs.

     15.4 ENTIRE AGREEMENT

          This Agreement, including Exhibits and all amendments thereto contain
the complete agreement between Owner and Operator with respect to the matters
contained herein

Steamboat Project O&M

                                       36

                          Operation and Maintenance Agreement - Steamboat Plants

and supersedes all prior and contemporaneous agreements and understandings,
whether written or oral, with respect to the matters contained herein.

     15.5 AMENDMENT

          No modification, amendment, or other change will be binding on any
Party unless consented to in writing by both Parties.

     15.6 GOVERNING LAW

          This Agreement shall be governed by the laws of the State of Nevada,
without regard to the conflict of laws principles thereof that may direct the
application of the law of another jurisdiction.

     15.7 NOTICES

          All notices required or provided for in this Agreement shall be in
writing and shall be delivered by hand; or sent by a recognized overnight mail
or courier service with delivery receipt requested; or sent by facsimile
transfer and acknowledged by recipient; Each entity comprising Owner appoints
ORNI 7, LLC as single addressee to receive any and all notices on its behalf
with respect to this Agreement, and notices shall be addressed to Operator, as
follows:

          If to Owner:      ORNI 7, LLC
                            980 Greg Street
                            Sparks, NV 89431-6039
                            Facsimile: (775) 356-9039
                            Attention: President

          If to Operator:   Ormat Nevada, Inc.
                            980 Greg Street

Steamboat Project O&M

                                       37

                          Operation and Maintenance Agreement - Steamboat Plants

                            Sparks, NV 89431-6039
                            Facsimile: (775) 356-9039
                            Attention: President

     Notices shall be effective when received by the Party to whom addressed.

     15.8 ADDITIONAL DOCUMENTS AND ACTIONS

          Each Party agrees to execute and deliver to the other such additional
documents, and take such additional actions, as may be reasonably required by
the other to effect the purposes and intent of this Agreement.

     15.9 WAIVER

          Failure by either Party to exercise any of its rights under this
Agreement shall not constitute a waiver of such rights. Neither Party shall be
deemed to have waived any right resulting from any failure to perform by the
other unless it has made such waiver specifically in writing.

     15.10 CAPTIONS

          The captions contained in this Agreement are for convenience of
reference only and in no way define, describe, extend or limit the scope or
intent of this Agreement or the intent of any provision contained herein.

     15.11 COUNTERPARTS

          This Agreement may be executed in one or more counterparts each of
which shall be deemed an original and all of which shall be deemed one and the
same Agreement.

Steamboat Project O&M

                                       38

                          Operation and Maintenance Agreement - Steamboat Plants

     15.12 CONFIDENTIALITY OF INFORMATION

          15.12.1 Each Party agrees, for itself and its Affiliates and their
directors, officers, employees and representatives, to keep confidential and not
make any unauthorized use of any confidential or proprietary information of the
other Party disclosed to such Party in and during the performance of this
Agreement, including documents, specifications, formulae, evaluations, methods,
processes, technical descriptions, reports and other data, records and
information (hereinafter the "Confidential Information").

          15.12.2 Confidential Information shall be identified in writing by the
disclosing Party, or if it is orally disclosed, the confidentiality thereof
shall be confirmed in writing by the disclosing Party promptly after such oral
disclosure. In any event, no disclosure shall be deemed to be Confidential
Information if such information:

               (a) Was known by the recipient prior to the disclosure thereof by
the disclosing Party;

               (b) Is, or shall become, other than by an act of the recipient,
generally available to the public;

               (c) Is lawfully made available to the recipient by a third party
in good faith;

               (d) Is required by law or governmental authority to be disclosed
to any person who is authorized by law to receive the same; provided, that to
the extent permitted by law and practical under the circumstances, the
disclosing party gives notice to the other party of the impending disclosure and
the opportunity to contest such disclosure in an appropriate proceeding.

          15.12.3 Each Party agrees that it will make available the other
Party's

Steamboat Project O&M

                                       39

                          Operation and Maintenance Agreement - Steamboat Plants

Confidential Information only on a "need to know" basis and that all persons to
whom such Confidential Information is made available will be made aware of the
strictly confidential nature of such Confidential Information.

          15.12.4 Notwithstanding the foregoing, Confidential Information may be
disclosed to any Lender and any Lender's advisors or potential lender in
connection with financing, refinancing, proposed financing or proposed
refinancing for the Facility as long as such lender or potential lender or
advisor complies with the provisions of this Section 15.12.

     15.13 NO THIRD PARTY BENEFICIARIES

          This Agreement is intended solely for the benefit of the Parties
hereto. Nothing in this Agreement shall be construed to create any duty to,
standard of care with reference to, any liability to, or any right of suit or
action in, any person or other legal entity not a party to this Agreement.

     15.14 NON-RECOURSE

          Neither Party shall have recourse hereunder, and no claim shall be
made, against any partner, shareholder, director, officer or other Affiliate of
the other Party, in such capacity, under this Agreement, and each Party's sole
recourse in the event of a breach hereunder by the other Party shall be against
the breaching Party's assets, irrespective of any failure to comply with
applicable law or any provision of this Agreement. Neither Party shall have any
right of subrogation to any claim of the other Party for any equity
contributions to such party from any shareholder or partner of such Party. This
acknowledgment and agreement are made expressly for the benefit of the partners,
shareholders, directors, officers and other Affiliates of the Parties. Nothing
containing in this Section 15.14 shall be construed to limit or affect any
obligations undertaken by any Affiliate of either Party or any of either Party's
or its Affiliates' partners, shareholders, directors or officers pursuant to a
separate agreement or instrument.

Steamboat Project O&M

                                       40

                          Operation and Maintenance Agreement - Steamboat Plants

     15.15 RIGHTS TO SET-OFF

          Each Party shall be entitled to set-off against any amounts owing by
it to the other Party under this Agreement any undisputed amounts owing by the
other Party to it under this Agreement.

     15.16 SURVIVAL OF CERTAIN PROVISIONS

          The provisions of Sections 7, 8.4, 9, 13, 15.1, 15.6, 15.12, 15.14 and
15.15 shall survive the termination of this Agreement.

     15.17 ADDITION OF STEAMBOAT DEVELOPMENT CORP. AS AN OWNER ENTITY

Each of the Parties acknowledges that Steamboat Development Corp. (a Utah
corporation incorporated in the State of [__]) is in the process of being
acquired by an Owner entity or Affiliate, and each further acknowledges and
agrees that, after the completion of such acquisition, Steamboat Development
Corp. may become an additional Owner party to this Agreement by executing its
signature below, and no further consent or agreements shall be required to
effect the addition of Steamboat Development Corp. as an Owner entity hereunder.
Upon its signature below, Steamboat Development Corp. shall become an additional
party to this Agreement, bound and benefited by its terms to the full extent as
all other Owner entities. This Agreement shall be fully binding and effective
with respect to Operator and all Owner entities other than Steamboat Development
Corp. prior and without relation to the addition of Steamboat Development Corp.
as an additional Owner entity.

     IN WITNESS WHEREOF the Parties have entered into this Operation and
Maintenance Agreement as of the date first written above.

Steamboat Project O&M

                                       41

                          Operation and Maintenance Agreement - Steamboat Plants

ORNI 7, LLC

By: /s/ Connie Stechman
    -----------------------------------
Name: Connie Stechman
Title: Controller

STEAMBOAT GEOTHERMAL LLC

By: /s/ Connie Stechman
    -----------------------------------
Name: Connie Stechman
Title: Controller

ORMAT NEVADA, INC.

By: /s/ Ran Raviv
    -----------------------------------
Name: Ran Raviv
Title: Vice President

Additional Owner entity:

STEAMBOAT DEVELOPMENT CORP.

By: /s/ Connie Stechman
    -----------------------------------
Name: Connie Stechman
Title: Assistant Secretary

Steamboat Project O&M

                                       42

Source: [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00076-of-00352.parquet"}, [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00076-of-00352.parquet"}]]