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. Xxxxx 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
Xxxxx Power Partners, a Nevada general partnership ("Seller") the general
partners of which are ESI BH Limited Partnership, a Delaware limited
partnership, with ESI Xxxxx, 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 Xxxxx Hot Springs Geothermal Associates ("Xxxxx") entered
into a Long-Term Agreement for the Purchase and Sale of Electricity dated
October 10, 1986 ("Xxxxx Contract").
b. A Settlement Agreement between Sierra and Xxxxx was entered into on
October 19, 1990 as a result of an action filed by Xxxxx on August 11, 1988 in
the Second Judicial District Court of the State of Nevada, in and for the County
of Washoe, captioned, "Xxxxx 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 Xxxxx
Contract into one single contract by terminating the Xxxxx 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 Xxxxx Contract from
Xxxxx Hot Springs Geothermal Associates to Seller ("Effective Date") and shall
continue until the Agreement is terminated.
3. Xxxxx Contract Termination. Upon the Effective Date of this Amendment, the
Xxxxx 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 xxxxxxx 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 xxxxxxx money deposit of $67,500. The
total xxxxxxx 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:
XXXXX POWER PARTNERS
BY: NEVADA GEOTHERMAL POWER PARTNERS,
LIMITED PARTNERSHIP, A GENERAL PARTNER
BY: HOT SPRINGS POWER COMPANY, ITS MANAGING
GENERAL PARTNER
BY: /s/ XXXXX X. XXXXXXXXXXX
---------------------------
XXXXX X. XXXXXXXXXXX,
PRESIDENT
DATE: 7/8/91
BY: ESI BH LIMITED PARTNERSHIP, A GENERAL
PARTNER
BY: ESI XXXXX, INC., ITS GENERAL PARTNER
BY: /s/ XXXXX X. XXXXXXXXX
---------------------------
XXXXX X. XXXXXXXXX
PRESIDENT
DATE:
-------------------------
SIERRA:
SIERRA PACIFIC POWER COMPANY
BY: /s/ XXXXXX X. XXXXXXX
---------------------------
XXXXXX X. XXXXXXX
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 Xxxxx 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.
XXXXX POWER PARTNERS
By: NEVADA GEOTHERMAL POWER PARTNERS, LIMITED PARTNERSHIP,
A GENERAL PARTNER
By: Hot Springs Power Company, a general partner
By: /s/ Xxxxx Xxxxxxxxxxx
------------------------
By: Xxxxx Xxxxxxxxxxx, President
Date: 11/20/91
By: ESI BH, LIMITED PARTNERSHIP, A GENERAL PARTNER
By: ESI BH Limited Partnership, a general partner
By: /s/ Xxxxx X. Xxxxxxxxx
------------------------
By: Xxxxx X. Xxxxxxxxx, President
Date: 12-9-91
SIERRA PACIFIC POWER COMPANY
By: /s/ Xxxxxx X. Xxxxxxx ---------
---------------------------- APPVD.
Xxxxxx X. Xxxxxxx, 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
0000 Xxxx Xxxx, Xxxx, Xxxxxx 15th Revised P.S.C.N. Sheet Xx. 0
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxxxxx Xx. 0 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
-----------------------------------------------------
0xx Xxxxxxx 0xx Xxxxxxx 0xx Xxxxxxx 0xx 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 Xxxxxxx X. Xxxxxxx
President
Advice No.: 000-X
Xxxxxxxx X
Page 1 of 4
EXHIBIT C
2 of 4
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 15th Revised P.S.C.N. Sheet Xx. 0
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxxxxxx X. Xxxxxxx
President
Advice No.: 000-X
Xxxxxxxx X
Page 2 of 4
EXHIBIT C
3 of 4
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 15th Revised P.S.C.N. Sheet Xx. 0
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxxxxxx X. Xxxxxxx
President
Advice No.: 000-X
Xxxxxxxx X
Page 3 of 4
EXHIBIT C
4 of 4
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxx Xx. 0 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 Xxxxxx X. Xxxxxxx
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 Xx. 0, XXXX Xxxxx Xx. 0,
Xxxxxxxx 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
XXXXX 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: Xxxxx X. Xxxxxxxxx, President
Date: 12-9-91
SIERRA PACIFIC POWER COMPANY
By: /s/ Xxxxxx X. Xxxxxxx
------------------------------------
Xxxxxx X. Xxxxxxx, 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 Xxxxx 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. Xx. 00
Xxxxxxxxxx Xxxxxxxx Xxxxx X.X.X.X. Xx. 00
--------------------------------------------------------------------------------
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:
Xxxx X. Xxxxx
EFFECTIVE: October 3, 1966 President
EXHIBIT G
2 of 12
SIERRA PACIFIC POWER COMPANY
RENO, NEVADA First Revised Sheet P.S.C.N. Xx. 00
Xxxxxxxxxx Xxxxxxxx Xxxxx X.X.X.X. Xx. 00
--------------------------------------------------------------------------------
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
EFFECTIVE: June 5, 1970 President
EXHIBIT G
4 of 12
SIERRA PACIFIC POWER COMPANY
RENO, NEVADA First Revised Sheet P.S.C.N. Xx. 00
Xxxxxxxxxx Xxxxxxxx Xxxxx X.X.X.X. Xx. 00
--------------------------------------------------------------------------------
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:
Xxxx X. Xxxxx
EFFECTIVE: October 3, 1966 President
EXHIBIT G
5 of 12
SIERRA PACIFIC POWER COMPANY
RENO, NEVADA First Revised Sheet P.S.C.N. Xx. 00
Xxxxxxxxxx Xxxxxxxx Xxxxx X.X.X.X. Xx. 00
--------------------------------------------------------------------------------
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
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:
Xxxx X. Xxxxx
EFFECTIVE: September 20, 1967 President
EXHIBIT G
12 of 12
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 273-E
Amended
--------------------------------------------------------------------------------
EXHIBIT H
1 of 3
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 6th Revised P.S.C.N. Sheet Xx. 00
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 292-E
--------------------------------------------------------------------------------
EXHIBIT H
2 of 3
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 5th Revised P.S.C.N. Sheet Xx. 00
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 xxxx 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
xxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 292-E
--------------------------------------------------------------------------------
EXHIBIT H
3 of 3
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 0xx Revised P.S.C.N. Sheet Xx. 00X
Xxxxxx Xx. Xxxxxxxx Xx. 0 Xxxxxxxxxx 0xx 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 xxxx, 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 292-E
--------------------------------------------------------------------------------
EXHIBIT I
1 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxxx X. Xxxxxxx
President
Advice No.: 298-E
--------------------------------------------------------------------------------
EXHIBIT I
2 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 301-E
--------------------------------------------------------------------------------
EXHIBIT I
3 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx Original _____ P.S.C.N. Sheet Xx. 00X
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 xxxxxxxx.
Tax Adjustment Charge
2% of total xxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 281-E
--------------------------------------------------------------------------------
EXHIBIT I
4 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx Original _____ P.S.C.N. Sheet Xx. 00X
Xxxxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 281-E
--------------------------------------------------------------------------------
EXHIBIT I
5 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxxx X. Xxxxxxx
President
Advice No.: 298-E
--------------------------------------------------------------------------------
EXHIBIT I
6 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx Original P.S.C.N. Sheet Xx. 00X
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 281-E
--------------------------------------------------------------------------------
EXHIBIT I
7 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 297-E
--------------------------------------------------------------------------------
EXHIBIT I
8 of 8
SIERRA PACIFIC POWER COMPANY
0000 Xxxx Xxxx, Xxxx, Xxxxxx 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 Xxxxxx X. Xxxxxxx
President
Advice No.: 281-E
--------------------------------------------------------------------------------
EXHIBIT J - 1 of 5
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 231-E
--------------------------------------------------------------------------------
EXHIBIT J - 2 of 5
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 231-E
--------------------------------------------------------------------------------
EXHIBIT J - 3 of 5
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 231-E
--------------------------------------------------------------------------------
EXHIBIT J - 4 of 5
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 1st Revised P.S.C.N. Sheet Xx. 00
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxx X. Xxxxxxx
President
Advice No.: 231-E
--------------------------------------------------------------------------------
EXHIBIT J - 5 of 5
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 1st Revised P.S.C.N. Sheet Xx. 00
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxx X. Xxxxxxx
President
Advice No.: 231-E
--------------------------------------------------------------------------------
EXHIBIT K - 1 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 3rd Revised P.S.C.N. Sheet Xx. 00
Xxxxxx Xx. Xxxxxxxx Xx. 0 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 Xxx X. Xxxxxxx
President
Advice No.: 176-E
--------------------------------------------------------------------------------
EXHIBIT K - 2 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 178-E
--------------------------------------------------------------------------------
Appendix C
Page 2 of 7
EXHIBIT K - 3 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 178-E
--------------------------------------------------------------------------------
Appendix C
Page 3 of 7
EXHIBIT K - 4 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 189-E
--------------------------------------------------------------------------------
Appendix C
Page 4 of 7
EXHIBIT K - 5 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 178-E
EXHIBIT K - 6 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
President
Advice No.: 178-E
--------------------------------------------------------------------------------
Appendix C
Page 6 of 7
EXHIBIT K - 7 of 7
SIERRA PACIFIC POWER COMPANY
000 X. Xxxxx Xxxx, Xxxx, Xxxxxx 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 Xxx X. Xxxxxxx
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]
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CHG DATE DESCRIPTION DWN DSGN CHKD APVD
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SHEET 1 OF 13
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VOL SECT PAGE
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1 2.2
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1 2/84 Added 1 3 Generation Above 1MW GWC
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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
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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
-----------------
-----------------
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Appendix G
Page 2 of 13
EXHIBIT L (1) - 3 of 13
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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.
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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
-----------------
-----------------
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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.
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[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
-----------------
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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
-----------------
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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.
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[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
-----------------
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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.
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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
-----------------
-----------------
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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.
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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
-----------------
-----------------
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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
X. XXXXX
--------------------------------------------------------------------
1 ADDED PAR 1.3 2/84 ___ __________ ENGINEER
---------------------------------------------
CH_ DESCRIPTION DATE ENG APPRV'D X. XXXXXX RENO SIERRA PACIFIC POWER CO. NEVADA
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Appendix G
Page 9 of 13
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EXHIBIT L (1) - 10 OF 13
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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
X.XXXXX
-------------------------------------------------------------------
1 ADDED PAR 1.3 2/84 ___ ILLEGIBLE ENGINEER
-----------------------------------------------
CHG DESCRIPTION DATE ENG APPRV'D X. XXXXXX RENO SIERRA PACIFIC POWER CO. NEVADA
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Appendix G
Page 10 of 13
EXHIBIT L (1) - 11 of 13
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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 (000) 000-0000. 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:
x Xxxxx 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.
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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. Xxxx Job No. 20177
Xxxxx 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 Xxx Xxxx Co.
---------------------
TIC
DRY TYPE AIR CORE SHUNT REACTOR Specification No. 3600-13
Nevada Geothermal Power Partners, Ltd. Xxxx Job No. 20177
Xxxxx 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 - Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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 Xxx Xxxx 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 Xxx
Xxxx 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. Xxxx Job No. 20177
Xxxxx 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 Xxx Xxxx 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
Xxx Xxxx Co.
DRY TYPE AIR CORE SHUNT REACTOR Specification No. 3600-13
Nevada Geothermal Power Partners, Ltd. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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 Xxx Xxxx Co.
----------------------
TIC
LIQUID FILLED SUBSTATION TRANSFORMER A Specification No. 3600-8
Nevada Geothermal Power Partners, Ltd. Xxxx Job No. 20177
Xxxxx 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: Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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. Xxxx Job No. 20177
Xxxxx 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 xxxxx to all production and data from the well tests,
be used for the Project injection xxxxx, 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 xxxxx
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 xxxxx 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 xxxxx.
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. Xxxx Job No. 20177
Xxxxx 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 load
