Document:

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                                                                   Exhibit 10(P)

                                                      Amendatory Agreement No. 1
                                                  Contract No. DE-MS79-88BP92436
                                                         01/26/95

                              AMENDATORY AGREEMENT
                                 executed by the
                            UNITED STATES OF AMERICA
                              DEPARTMENT OF ENERGY
                              acting by and through
                         BONNEVILLE POWER ADMINISTRATION
                                       and
                          SIERRA PACIFIC POWER COMPANY

                                Index to Section

--------------------------------------------------------------------------------
Section                                                                 Page
   1.  Amendment Term .................................................  2
   2.  Exhibits .......................................................  2
   3.  Provisions Relating to Delivery ................................  2
   4.  Planning Information ...........................................  4
   5.  Scheduling Provisions ..........................................  5
   6.  Purchase Displacement Cost .....................................  5
   7.  Points of Delivery .............................................  5
   8.  System and Communication Upgrades ..............................  6
   9.  Power Factor ...................................................  7
   10. FERC Application ...............................................  8
   11. Status of Amendment ............................................  8
   12. Multiple Originals .............................................  8

       Exhibits revised, replaced, or added:
       Exhibit B  (Points of Delivery and Points of Replacement) ......  2
       Exhibit C  (Transfer Charges and Loss Factors) .................  2
       Exhibit E  (Special Charges) ...................................  2
       Exhibit F  (Monthly Local Facility Charge for Carlin Area
                       Upgrades) ......................................  2
       Exhibit G  (Transmission Reservation) ..........................  2
       Exhibit H  (Termination Charge Methodology) ....................  2
       Exhibit I  (Determination of Local Facility Charge) ............  2
       Exhibit J  (Sample Calculations of Annual Charges for
                       Reduction in Service) ..........................  2
       Exhibit K  (Sample Calculations of Transmission
                       Reservation Termination) .......................  2

<PAGE>

     This AMENDATORY AGREEMENT, executed April 11, 1995, is entered into by the
UNITED STATES OF AMERICA (Government), Department of Energy, acting by and
through the Bonneville Power Administration (Bonneville), and SIERRA PACIFIC
POWER COMPANY (Company), a corporation of the State of Nevada. Bonneville and
Company are sometimes referred to collectively as "Parties."

                                   WITNESSETH:

     WHEREAS the Parties entered into a General Transfer Agreement (GTA),
Contract No. DE-MS79-88BP92436, dated February 25, 1988, which provides, among
other matters, for the transfer of electric power and energy to Wells Rural
Electric Company (Wells). The Company is currently providing up to 45 MW of
transfer service under the GTA. Bonneville delivers this electric power and
energy at the Midpoint Point of Replacement; and

     WHEREAS Bonneville has requested the Company provide additional firm
transfer service to Bonneville's Wells load and the Company has expressed a
desire to provide such additional transfer service. However, any additional
transmission service which is provided by the Company is subject to the same
terms and conditions as the existing 45MW of transfer service under the GTA
until the time that system improvement s are completed that result in an
increase of 200 MW or more to the Company's net import capability (System
Improvements); and

     WHEREAS the Company is undertaking local system additions and improvements
required to serve the Carlin Area Customer loads, hereinafter referred to as the
Carlin Area Upgrades, and Wells worked with the Company to choose the best plan
of service at the lowest possible cost; and

     WHEREAS Bonneville and the Company have agreed to undertake and participate
in joint engineering studies to develop a long-range plan of service designed to
address and resolve service limitations facing the Company's system; and

     WHEREAS the Company and Idaho Power Company (Idaho) jointly own the North
Valmy Electric Generation Station (Valmy), located near Battle Mountain, Nevada;
and

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     WHEREAS Bonneville intends to provide, or arrange to provide, scheduled
delivery of Valmy Generation to Carlin and Maggie Creek Subsidiaries; and

     WHEREAS Bonneville and the Company have agreed that the northbound/Valmy
schedules may be interrupted if the 345 kV line between Midpoint and Humboldt
(Line No. 3419) is unavailable;

     NOW, THEREFORE, in consideration of the promise and covenants contained
herein, the Parties agree to amend the GTA as follows:

1.       AMENDMENT TERM

         This Amendment shall be effective after Rural Electrification
         Administration approval of Revision No. 1 to Exhibit L of the Power
         Sales Contract (Contract No. DEMS79-81BP90571) between Bonneville and
         Wells and upon Federal Energy Regulatory Commission (FERC) acceptance
         of this Amendment in its entirety and without change ("Amendment
         Effective Date") and shall continue in effect concurrent with the term
         specified in section 1 of the GTA. If FERC does not accept this
         Amendment in its entirety and without change, the Parties shall
         determine whether both Parties are willing and able to modify this
         Amendment to comply with such FERC order. If the Parties are unable to
         reach an acceptable modification within a 30-day period, the Parties
         shall exercise best efforts to negotiate alternative arrangements to
         meet the same goals.

2.       EXHIBITS

         Section 3 of the GTA is amended to read as follows:

         "Exhibits A through J and any revisions thereto are made a part of this
         Agreement. The Company shall be the Transferor and Bonneville's
         Customer shall be the Transferee mentioned in Exhibit A."

3.       PROVISIONS RELATING TO DELIVERY

         Section 4(a) of the GTA is amended to read as follows:

                                      -2-

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         "(a)     Electric power and energy shall be made available by the
                  Company at all times during the term hereof at the points of
                  delivery described in Exhibit B (Points of Delivery), in the
                  amount of Bonneville's Customer's requirements at such points
                  and the approximate voltages specified therein; provided
                  however, that Bonneville shall make available, pursuant to
                  section 5, electric power and energy at the Points of
                  Replacement specified in Exhibit B; provided, further, that
                  the Transfer Trip load as defined in section 4(f), may be
                  interrupted:

                  (1)      in the event of an outage on the
                           Midpoint-Humboldt-Coyote Creek 345 kV transmission
                           lines which reduces the Company's import capability,
                           or

                  (2)      in the event of an outage on the Company's 120 kV
                           transmission system serving the Carlin area and the
                           Company is unable to serve both the Company's
                           customer loads and Bonneville's Customer loads, in
                           which case interruption of the loads will be shared
                           equitably between the Parties, or

                  (3)      in the event of Loss of Line No. 3419 and the Company
                           is unable to provide service to Bonneville's loads
                           from inside the Company's import boundary.

                  In no event shall the Company be obligated to import electric
                  power and energy hereunder at a demand level in excess of the
                  import demand limit specified in Exhibit B, except where
                  otherwise agreed. If any of Bonneville's Customer's load is
                  interrupted, the Company may provide service pursuant to
                  section 6 of the GTA.

                  In the event insufficient import capability to the Company's
                  system exists, Bonneville shall provide power in excess of the
                  demand limit from inside the Company's import boundary in a
                  manner specified by the Company, or reduce deliveries
                  accordingly. The Company will give priority to residential
                  customers and other critical loads in its use of Valmy
                  Generation."

                                      -3-

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4.       PLANNING INFORMATION

         Section 4(c) of the GTA is amended to read as follows:

         "(c)     Bonneville shall submit, within 45 days following acceptance
                  by FERC for filing (Filing Date), a one-time 10-year forecast
                  listing peak demands, by Point of Delivery, for each calendar
                  month of the 10-year period. This forecast shall be
                  incorporated in Exhibit G. Then, beginning in year 6 of this
                  Amendment and continuing for the term of this Agreement,
                  Bonneville shall submit, by July 1 of each year, a 5-year
                  forecast of peak demands by Points of Delivery, for each
                  calendar month of the 5-year period. Exhibit G attached hereto
                  shall be modified each July 1 to incorporate the fifth year of
                  such 5-year forecast. Such information shall be relied upon by
                  the Company for system and marketing planning.

                  In the event Bonneville desires to increase forecast demands
                  for a month or months for which a forecast peak demand has
                  been previously established, the Company shall, at its sole
                  discretion, determine whether such incremental capacity can be
                  made available to Bonneville. In the event the Company is
                  unable to serve the incremental demand requested by
                  Bonneville, it shall provide notice of its inability to do so
                  within 60 days of Bonneville's increased Exhibit G forecast
                  submittal. The Company may, but shall not be obligated under
                  this Agreement to, provide import capacity in excess of the
                  amounts established pursuant to Exhibit G of this Agreement.

                  In the event Bonneville desires to reduce the forecast demands
                  of this Agreement, the Company shall made a reasonable effort
                  to market the resulting excess capacity reserved for
                  Bonneville; however, if this excess capacity becomes unused,
                  Bonneville will be subject to a Charge for Reduction of
                  Service as shown in Exhibits E and G."

                                      -4-

<PAGE>

5.       SCHEDULING PROVISIONS

         Section 8(a) of the GTA is amended to read as follows:

         "(a)     Bonneville shall provide, or arrange to have provided, a
                  separate schedule to the Company for each hour, to the Points
                  of Replacement or to other mutually agreeable points of
                  replacement, for the following:

                  (1)      in accordance with section 5 of the GTA, electric
                           power and energy which the Company will deliver to
                           Bonneville's Customers at the Points of Delivery; and

                  (2)      in accordance with section 6 of the GTA, any
                           emergency power requested for such hour by the
                           Company which Bonneville determined can be made
                           available."

6.       PURCHASE DISPLACEMENT COST

         Section 9(h) shall become section 9(e) and the previous sections 9(e),
         9(f) and 9(g) of the GTA are deleted in their entirety.

7.       POINTS OF DELIVERY

         Section 11(b) of the GTA is amended to read as follows:

         "(b)     If Bonneville desires the Company to provide transfer service
                  to new points of delivery, add additional capacity at existing
                  Points of Delivery, or increase demand limits as specified in
                  Exhibit B to serve Bonneville's load growth or new loads
                  within Well's service territory, then Bonneville shall make a
                  written request to the Company as early as possible prior to
                  the date Bonneville requests such change to be effective.
                  Bonneville's written request shall include the transfer
                  capacity requirement and required energization date. The
                  Company shall respond in writing to Bonneville's request
                  within 60 days of such request.

                                      -5-

<PAGE>

                  In the event of any disputes regarding the Company's response,
                  Bonneville retains any rights it otherwise has to resolve the
                  dispute."

8.       SYSTEM AND COMMUNICATION UPGRADES

         This section shall be added and designated as section 23 of the GTA and
         shall read as follows:

         "23.     SYSTEM AND COMMUNICATION UPGRADES

                  (a)      The Company intends to provide and operate Carlin
                           Area Upgrades sufficient to serve approximately 300
                           MW of load which will accommodate 350 to 385 MVA of
                           fault duty at the Maggie Creek substation 120 kV bus.
                           Such equipment shall be in service prior to an
                           agreed-upon date. The Bonneville share of the Carlin
                           Area Upgrades shall consist of thirty-three percent
                           (33%) of the new Bell Creek Switch Station, fifty
                           percent (50%) of the Coyote Creek Substation
                           expansion, one hundred percent (100%) of the Maggie
                           Creek Switch Station expansion, and one hundred
                           percent (100%) of the new Bell Creek to Maggie Creek
                           120 kV transmission line. The Bonneville share of the
                           Carlin Area Upgrades is estimated as $9,258,000. This
                           amount shall be adjusted upward or downward in the
                           event the Company's actual cost of construction,
                           rounded to the nearest thousand, varies from the
                           estimate. Bonneville shall be allowed 2 years from
                           the completion of the construction to perform an
                           audit of the final construction expenditures and to
                           dispute payment of expenditures based upon the audit.
                           The Company shall bear its pro-rata share of any
                           increase or decrease in the costs resulting from
                           Bonneville's audit. Bonneville and the Company agree
                           to act in good faith to resolve any conflicts or
                           disagreements regarding costs, cost allocations,
                           overheads, or any other direct assignments affecting
                           the Local Facility Charge. Bonneville shall pay the
                           Company for its share of the Carlin Area Upgrades as
                           specified in Exhibits E and F. Prior to the

                                      -6-

<PAGE>

                           installation of the System Improvements, any transfer
                           service shall be designated as Transfer Trip Load.

                  (b)      The Company, at Bonneville's expense, shall design
                           and install selective/redundant transfer trip and
                           communication equipment to accommodate Bonneville's
                           request for an increase in transfer services. Such
                           equipment shall be in service prior to an agreed upon
                           date of any increase in the transfer services as
                           provided for in section 23(a). The Company shall
                           provide to Bonneville an itemized statement of the
                           expenses incurred for such equipment. Bonneville
                           shall pay the Company within 30 calendar days
                           following the Amendment Effective Date, including
                           related taxes incurred by the Company, if required."

9.       POWER FACTOR

         This section shall be added and designated as section 25 of the GTA and
         shall read as follows:

         "25.     POWER FACTOR

                  The on-peak power factor at the Points of Delivery specified
                  in Exhibit B shall be within ninety-eight percent (98%)
                  leading or lagging. The power factor for all other hours shall
                  be within ninety-five percent (95%) leading or lagging.

                  The on-peak hours shall be defined as follows:

                       Months                     On-Peak Hours

                       October through May        5:01 p.m. to 10:00 p.m. daily

                       June through September     10:01 a.m. to 10:00 p.m. daily

                  Bonneville shall provide the Company with access to
                  Bonneville's meters associated with Bonneville's Points of
                  Delivery specified in Exhibit B."

                                      -7-

<PAGE>

10.      FERC APPLICATION

         Section 13(d) of the GTA is added and shall read as follows:

         "(d)     Nothing herein is intended to limit the rights of Bonneville
                  to make application to FERC for a change in rates under
                  Section 206 of the Federal Power Act and pursuant to FERC's
                  Rules and Regulations promulgated thereunder."

11.      STATUS OF AMENDMENT

         It is expressly understood and agreed by the Parties that all the
         terms, conditions, and provisions of this Agreement are made part of
         the GTA upon the Amendment Effective Date as though the GTA were
         expressly rewritten to incorporate and include the contents of this
         Amendment. None of the terms or conditions in this Amendment shall be
         considered a precedent for any future agreement between the Parties.

12.      MULTIPLE ORIGINALS

         Two (2) copies of this Amendment have been executed by the Parties.
         Each executed copy shall be deemed an original.

         IN WITNESS WHEREOF, the Parties hereto have executed this Amendment.

                                    UNITED STATES OF AMERICA
                                    Department of Energy
                                    Bonneville Power Administration

                                    By
                                       ---------------------------------------
                                       Customer Account Executive

                                    Name
                                         -------------------------------------
                                    (Print/Type)

                                    Date
                                         -------------------------------------

                                      -8-

<PAGE>

SIERRA PACIFIC POWER COMPANY

By
   ---------------------------------------------------
   Customer Account Executive

Name
     -------------------------------------------------
(Print/Type)

Date
     -------------------------------------------------

                                      -9-<PAGE>

                                                                   Exhibit 10(Q)

                                                  Amendatory Agreement No. 2
                                                  Contract No. DE-MS79-88BP92436
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

                              AMENDATORY AGREEMENT
                                 executed by the
                            UNITED STATES OF AMERICA
                              DEPARTMENT OF ENERGY
                              acting by and through
                         BONNEVILLE POWER ADMINISTRATION
                                       and
                          SIERRA PACIFIC POWER COMPANY

                                Index to Sections
--------------------------------------------------------------------------------
Section                                                                     Page

   1.    Amendment Transfer Service.......................................   2
   2.    Amendment Term...................................................   2
   3.    Provisions Relating to Delivery..................................   2
   4.    Payment for Transfer of Power....................................   3
   5.    Status of Amendment..............................................   3
   6.    Multiple Originals...............................................   3

         Exhibits revised
         Exhibit B  (Points of Delivery and Points of Replacement)........   1
         Exhibit C  (Transfer Charges and Loss Factors)...................   1

                                   Page 1 of 4

<PAGE>

     This AMENDATORY AGREEMENT, executed July 5, 2000, is entered into by the
UNITED STATES OF AMERICA (Government), Department of Energy, acting by and
through the Bonneville Power Administration (Bonneville), and SIERRA PACIFIC
POWER COMPANY (Company), a corporation of the State of Nevada. Bonneville and
Company are sometimes referred to collectively as "Parties."

WITNESSETH:

     WHEREAS, the Parties entered into a General Transfer Agreement (GTA),
Contract No. DE-MS79-88BP92436, dated February 25, 1988 and amended April 11,
1995, which provides, among other matters, for the transfer of electric power
and energy to Wells Rural Electric Company (Wells). The Company is currently
providing up to 65 MW of transfer service under the GTA. Bonneville delivers
this electric power and energy at the Hilltop Point of Replacement (POR); and

     WHEREAS, the Company has completed construction on a 345 kilovolt (kV)
transmission line between the Company's North Valley Road Substation in Reno,
Nevada and the Company's Hilltop Substation near Alturas, California
(Reno-Alturas Transmission Project); and

     WHEREAS, the Reno-Alturas Transmission Project is interconnected to
Bonneville's Malin-Warner 230 kV Line (Malin-Warner Line); and

     WHEREAS, Bonneville has by letter dated August 3, 1998 exercised its option
to transfer its POR from Midpoint to Hilltop;

     NOW, THEREFORE, in consideration of the promises and covenants contained
herein, the Parties agree to amend the GTA as follows:

1.   AMENDMENT TRANSFER SERVICE

Exhibit B of the GTA is amended pursuant to the following:

"Company shall provide service under the GTA up to a total demand limit of 110
MW, including service delivered pursuant to Contract Number DE-MS79-79BP90000,
to include Maggie Creek, Carlin, McNabb, Jiggs Lee, and Winnemucca. Point of
Replacement shall be at the Hilltop Point of Interconnection.

2.   AMENDMENT TERM

Subject to the approval of the Federal Energy Regulatory Commission, this
Amendment shall be effective at 2400 hours on the date of execution (Amendment
Effective Date).

3.   PROVISIONS RELATING TO DELIVERY

Section 4(a) of the GTA is amended to read as follows:

                                   Page 2 of 4

<PAGE>

"(a) Electric power and energy shall be made available by the Company at all
     times during the term hereof at the points of delivery described in Exhibit
     B (Points of Delivery), in the amount of Bonneville's Customer requirements
     at such points and at the approximate voltages specified therein; provided,
     however, that Bonneville shall make available, pursuant to section 5,
     electric power and energy at the Points of Replacement specified in Exhibit
     B; provided, however, that in the event of an outage on the Company's 120
     kV transmission system serving the Carlin area and the company is unable to
     serve both the Company's customer loads and Bonneville's Customer loads, in
     which case, to the extent possible, interruption of the loads will be
     shared equitably between the Parties.

     In no event shall the Company be obligated to import electric power and
     energy hereunder at a demand level in excess of the import demand limit
     specified in Exhibit B, except where otherwise agreed. If any of
     Bonneville's Customer load is interrupted, the Company may provide service
     pursuant to section 6 of the GTA.

     In the event insufficient import capability to the Company's system exists,
     Bonneville shall provide power in excess of the demand limit from inside
     the Company's import boundary in a manner specified by the Company, or
     reduce deliveries accordingly. The Company will give priority to
     residential customers and other critical loads in its use of Valmy
     Generation."

4.   PAYMENT FOR TRANSFER OF POWER

Section 9(a) of the GTA is amended to read as follows:

"(a) For the use of Company services and facilities in transferring electric
     power and energy hereunder, Bonneville shall pay the Company each month in
     the term hereof an amount equal to the sum for all Points of Delivery of
     the greater of (1), (2) or (3) below for each point of delivery; provided
     however, that certain Points of Delivery shall be coincidentally combined
     as specified in Exhibit B".

Section 9(a)(3) of the GTA is amended to read as follows:

     "(3) The product of [1] the Transmission Reservation shown in Exhibit G for
          the current month and [2] the Transfer Charge."

5.   STATUS OF AMENDMENT

     It is expressly understood and agreed by the Parties that all the terms,
conditions, and provisions of this Amendment are made part of the GTA upon the
Amendment Effective Date as though the GTA were expressly rewritten to
incorporate and include the contents of this Amendment. None of the terms or
conditions in this Amendment shall be considered a precedent for any future
agreement between the Parties.

6.   MULTIPLE ORIGINALS

     Two (2) copies of this Amendment have been executed by the Parties. Each
executed copy shall be deemed an original.

                                   Page 3 of 4

<PAGE>

     IN WITNESS WHEREOF, the Parties hereto have executed this Amendment.

SIERRA PACIFIC POWER COMPANY                  UNITED STATES OF AMERICA
                                              Department of Energy
                                              Bonneville Power Administration

By:                                           By:
   ----------------------------------------      -------------------------------

Name:    Gary Porter                          Name:    Patrick McRae

Title:   Executive Director of Transmission   Title:   Manager, Transmission &
                                                       Reserve Services - PBL

Date:  6/30/00                                Date:  7/5/00

                                   Page 4 of 4

<PAGE>

                                                  Amendatory Agreement No. 2
                                                  Exhibit B, Page 1 of 4
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

                  POINTS OF DELIVERY AND POINTS OF REPLACEMENT

A.   Carlin Substation Point of Delivery - Not to exceed 10MW without prior
                                           notification and approval by Company

     Bonneville Customer: Wells.

     Location: The point near Wells Carlin Substation where the 115 kV
     facilities of the Company and Wells are connected.

     Voltage: 120kV.

     Metering: Coincidentally with the Maggie Creek Point of Delivery, Jiggs Lee
     Point of Delivery, and McNabb Point of Delivery, at the following
     locations:

     (1)  Carlin Point of Metering: In Wells' Carlin Substation in the 25kV
          circuit over which such electric power and energy flows.

     (2)  Rain Point of Metering: In the Rain Point of Delivery located on
          Wells' Pine Valley 14.4 / 24.9 kV distribution line where Wells
          delivers power and energy to the Company's load.

     (3)  Sprint Point of Metering: In the U.S. Sprint Point of Delivery on
          Wells' Pine Valley 14.4 / 24.9 kV distribution line where Wells
          delivers power and energy to the Company's load.

     Demand Limit: Service to this Point of Delivery shall not exceed 10 MW
     without prior notification and approval by the Company. Service to this
     Point of Delivery, the Maggie Creek Point of Delivery, the McNabb Point of
     Delivery, the Jiggs Lee Point of Delivery, and the demand pursuant to
     Contract Number DE-MS-79-79BP90000, shall not exceed 110 MW, plus losses as
     specified in Exhibit C.

     Adjustment: There shall be an adjustment for losses between the Points of
     Metering and the Point of Delivery.

     Amount of Power Delivered: The amount of electric energy and reactive power
     delivered hereunder and each of the Integrated Demands for any hour during
     the term hereof shall be the sum of the following:

                                  Page 1 of 4

<PAGE>

                                                  Amendatory Agreement No. 2
                                                  Exhibit B, Page 2 of 4
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

     (1)  the amount metered at the Carlin Point of Metering, after adjusting
          losses as specified in the GTA, less the sum of the amount metered at
          the Rain Point of Metering, after adjusting for losses as specified
          above, and the U.S. Sprint Point of Metering, after adjusting for
          losses as specified above;

     (2)  the amount metered at the Maggie Creek Point of Metering, as described
          below, after adjusting for losses as specified above;

     (3)  the amount metered at the McNabb Point of Metering, as described
          below, after adjusting for losses as specified above;

     (4)  the amount metered at the Jiggs Lee Point of Metering, as described
          below, after adjusting for losses as specified above; and

     (5)  the amount metered under Contract Number DE-MS79-79BP9000 for the
          Harney Winnemucca Point of Metering.

B.   Maggie Creek Point of Delivery - Not to exceed 85 MW without prior
                                      notification and approval by SPPCo.

     Bonneville Customer: Wells.

     Location: The point in the Company's Eightmile Creek-Maggie Creek 120 kV
     transmission line where the tap to Wells' Gold Quarry Substation is
     connected.

     Voltage: 120kV.

     Metering: Coincidentally with the Carlin Substation, Jiggs Lee Point of
     Delivery, and McNabb Points of Delivery, in Maggie Creek Substation on the
     120 kV line to Gold Quarry.

     Demand Limit: Service to this Point of Delivery shall not exceed 85 MW
     without prior notification and approval by Company. Service to this Point
     of Delivery, the Carlin Substation Point of Delivery, the McNabb Point of
     Delivery, the Jiggs Lee Point of Delivery, and the demand pursuant to
     Contract Number DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as
     specified in Exhibit C.

     Amount of Power Delivered: The amount of electric power and energy
     delivered shall be determined coincidentally with the Carlin Substation
     Point of Delivery, the Jiggs Lee Point of Delivery, and the McNabb Point of
     Delivery as specified in the GTA, as well as

                                  Page 2 of 4

<PAGE>
                                                  Amendatory Agreement No. 2
                                                  Exhibit B, Page 3 of 4
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

     the amount metered under Contract Number DE-MS79-79BP9000 for the Harney
     Winnemucca Point of Metering.

     Adjustment: There shall be an adjustment for losses between the Point of
     Metering and the Point of Delivery.

C.   McNabb Point of Delivery - Not to exceed 500 kW without prior notification
                                and approval by the Company.

     Bonneville Customer: Wells.

     Location: The point in the Company's Tonkin Springs-Cortez Tap 60 kV
     transmission line where the tap to Wells' McNabb substation is located.

     Voltage: 60 kV.

     Metering: Coincidentally with the Carlin Substation, Jiggs Lee Point of
     Delivery, and Maggie Creek Points of Delivery, in McNabb Substation on the
     14.40 kV side of the 60 / 14.4 kV transformer.

     Demand Limit: Service to this Point of Delivery shall not exceed 500 kW
     without prior notification and approval by Company. Service to this Point
     of Delivery, the Carlin Substation Point of Delivery, the Maggie Creek
     Point of Delivery, Jiggs Lee Point of Delivery, and the demand pursuant to
     Contract Number DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as
     specified in Exhibit C.

     Amount of Power Delivered: The amount of electric power and energy
     delivered shall be determined coincidentally with the Carlin Substation
     Point of Delivery, the Jiggs Lee Point of Delivery, and the Maggie Creek
     Point of Delivery as specified in the GTA, as well as the amount metered
     under Contract Number DE-MS79-79BP9000 for the Harney Winnemucca Point of
     Metering.

     Adjustment: There shall be an adjustment for losses between the Point of
     Metering and the Point of Delivery.

D.   Jiggs Lee Point of Delivery - Not to exceed 2 MW without prior notification
                                   and approval by Company.

     Bonneville Customer: Wells.

                                  Page 3 of 4

<PAGE>

                                                  Amendatory Agreement No. 2
                                                  Exhibit B, Page 4 of 4
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

     Location: The point in the Company's 208 Distribution line where Company
     connects to Wells distribution line. The point in the Company's 208
     Distribution line where the Service territory starts.

     Voltage: 24.9 kV.

     Metering: The point in the Company's 208 Distribution line where Company
     connects to Wells distribution line where the Service territory starts.

     Demand Limit: Service to this Point of Delivery shall not exceed 2MW
     without prior notification and approval by Company. Service to this Point
     of Delivery, the Carlin Substation Point of Delivery, the Maggie Creek
     Point of Delivery, the McNabb Point of Delivery, and the demand pursuant to
     Contract No. DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as
     specified in Exhibit C.

     Amount of Power Delivered: The amount of electric power and energy
     delivered shall be determined coincidentally with the Carlin Substation
     Point of Delivery and the Maggie Creek Point of Delivery as specified in
     the GTA, as well as the amount metered under Contract Number
     DE-MS79-79BP9000 for the Harney Winnemucca Point of Metering.

     Adjustment: There shall be an adjustment for losses between the Point of
     Metering and the Point of Delivery.

E.   Points of Replacement

     Hilltop Point of Replacement

          Location: The 230 kV bus at the Hilltop Substation where the Company
          has a right to accept deliveries of power and energy from Bonneville.

          Voltage: 230/345 kV.

     Valmy Point of Replacement

          Location: The 345 kV bus at the Company's Valmy Substation. This Point
          of Replacement is to be used for amounts scheduled from Valmy.

          Voltage: 345 kV.

                                  Page 4 of 4

<PAGE>

                                                  Amendatory Agreement No. 2
                                                  Exhibit C, Page 1 of 1
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

                        TRANSFER CHARGES AND LOSS FACTORS

                      Transfer Charge/1/   Transfer Trip Load   Loss Factor/2/
Point of Delivery        ($/kW-mo)                (MW)               (%)

Carlin Substation          3.40                    0                 4.0

Maggie Creek               3.40                    0                 4.0

McNabb                     3.40                    0                 4.0

Jiggs Lee                  3.40                    0                 4.0

----------
/1/  Transfer charge at the FERC-approved rate.

/2/  Based on Company average incremental transmission losses, from Schedule RT,
     section T-1, Transmission Service, which is reviewed and adjusted as
     necessary.

                                  Page 1 of 1

<PAGE>

                                                  Amendatory Agreement No. 2
                                                  Exhibit G, Page 1 of 1
                                                  Contract No. DE-MS79-88BP92436
                                                  Sierra Pacific Power Company
                                                  Effective at 2400 Hours on the
                                                  Amendment Effective Date

                            TRANSMISSION RESERVATION

1.   The forecast monthly peak ("Transmission Reservation") given below, in
     megawatts, shall be the basis for calculating the minimum monthly
     reservation fee, ie: Transmission Reservation* $3.40kW mo.

2.   For the period of August 1995 through July 2000, the annual Transmission
     Reservation, as applied in Exhibit E, shall be no less than 100 percent of
     the forecast monthly peak demand given below.

3.   For the period of August 2000 through July 2005, the annual Transmission
     Reservation shall be no less than 85 percent of the forecast monthly peak
     demand given below, in megawatts.

<TABLE>
<CAPTION>
--------------------------------------------------------------------------------------
        1995    1996    1997    1998    1999   2000   2001   2002   2003   2004   2005
--------------------------------------------------------------------------------------
<S>     <C>     <C>     <C>     <C>     <C>    <C>    <C>    <C>    <C>    <C>    <C>
Jan             70.61   71.61   71.61   70.0   70.0   70.1   70.2   70.3   70.3   70.4
--------------------------------------------------------------------------------------
Feb             70.51   71.51   71.51   70.1   70.2   70.3   70.3   70.4   70.5   70.6
--------------------------------------------------------------------------------------
Mar             69.80   70.80   70.80   69.3   69.3   69.4   69.4   69.5   69.6   69.6
--------------------------------------------------------------------------------------
Apr             69.29   70.26   70.26   69.2   69.2   69.3   69.3   69.4   69.5   69.5
--------------------------------------------------------------------------------------
May             69.71   70.71   70.71   68.6   68.6   68.7   68.7   68.8   68.8   68.9
--------------------------------------------------------------------------------------
Jun             71.56   72.56   72.56   68.2   68.2   68.3   68.3   68.4   68.4   68.5
--------------------------------------------------------------------------------------
Jul     69.64   69.64   70.64   69.64   68.6   68.7   68.7   68.8   68.8   68.9   69.0
--------------------------------------------------------------------------------------
Aug     69.71   69.71   70.71   69.71   68.3   68.4   68.4   68.5   68.5   68.6   68.6
--------------------------------------------------------------------------------------
Sep     69.29   69.29   70.29   69.29   68.6   68.6   68.7   68.7   68.8   68.9   68.9
--------------------------------------------------------------------------------------
Oct     69.76   69.76   70.76   69.76   68.4   68.4   68.5   68.5   68.6   68.6   68.7
--------------------------------------------------------------------------------------
Nov     70.22   70.22   71.22   70.22   69.5   69.6   69.6   69.7   69.8   69.9   69.9
--------------------------------------------------------------------------------------
Dec     70.48   70.48   71.48   70.48   70.0   70.1   70.1   70.2   70.3   70.4   70.5
--------------------------------------------------------------------------------------
</TABLE>

4.   Transmission Reservations for years after July 5, 2004, through 2010 shall
     be subject to a Charge for Reduction of Service based on 85 percent of the
     Forecasted Monthly Peak Demand.

AMENDMENT TERM

     Subject to the approval of the Federal Energy Regulatory Commission, this
     Amendment shall be effective at 2400 hours on the date of execution
     (Amendment Effective Date) with no adjustments for prior periods under the
     terms and conditions of Amendment.

                                  Page 1 of 1

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