Exhibit 10.3.34
Schedule A
Item 29
IID - EDISON
TRANSMISSION SERVICE AGREEMENT
FOR ALTERNATIVE RESOURCES
BETWEEN
IMPERIAL IRRIGATION DISTRICT
AND
SOUTHERN CALIFORNIA EDISON COMPANY
TABLE OF CONTENTS
Section Title Page
1 PARTIES 1
2 RECITALS 1
3 AGREEMENT 2
4 DEFINITIONS 2
5 TERM 5
6 TRANSMISSION SERVICE 6
7 TRANSMISSION LOSSES 10
8 CHARGES 11
9 BILLING AND PAYMENT 13
10 LIABILITY 15
11 AUDITING 18
12 AUTHORIZED REPRESENTATIVES 18
13 NO DEDICATION OF FACILITIES 19
l's HON-WAIVER 19
15 NO THIRD PARTY RIGHTS 19
16 UNCONTROLLABLE FORCES 19
17 ASSIGNMENTS 21
18 GOVERNING LAW 21
19 NOTICES 21
20 SIGNATURE CLAUSE 23
TABLE OF CONTENTS
Page
EXHIBIT I - DEVELOPMENTS AND METHODOLOGIES FOR
TRANSMISSION AND SUBTRANSMISSION SERVICE
CHARGES AND SCHEDULING FEE (EI-1-EI-14)
EXHIBIT II - TRANSMISSION SERVICE FOR EI-15
THE BRAWLEY GEOTHERMAL POWER
PLANT UNIT NO. 1
EXHIBIT III - TRANSMISSION SERVICE FOR THE EI-16
SALTON SEA GEOTHERMAL POWER
PLANT UNIT NO. 1
EXHIBIT IV - TRANSMISSION SERVICE FOR THE EI-17
MAGMA EAST MESA GEOTHERMAL POWER
PLANT UNIT NO. I
EXHIBIT V - TRANSMISSION SERVICE FOR THE EI-18
HEBER GEOTHERMAL POWER
PLANT UNIT NO. 1
EXHIBIT VI - TRANSMISSION SERVICE FOR EI-19
THE VULCAN POWER GEOTHERMAL
POWER PLANT UNIT NO. 1
EXHIBIT VII - TRANSMISSION SERVICE FOR THE EI-20
WESTERN POWER GROUP BIOMASS POWER
PLANT UNIT NO. 1
EXHIBIT VIII- TRANSMISSION SERVICE FOR EI-21
THE ORMESA GEOTHERMAL POWER
PLANT UNIT NO. 1
IID - EDISON
TRANSMISSION SERVICE AGREEMENT
FOR ALTERNATIVE RESOURCES
1. PARTIES: The Parties to this Agreement are Imperial Irrigation
District, organized under the Water Code of the State of California ("IID"), and
Southern California Edison Company, a California corporation ("Edison"),
hereinafter sometimes referred to individually as "Party," and collectively as
"Parties".
2. RECITALS: This Agreement is made with reference to the following
facts, among others:
2.1 Edison plans to develop its own alternative resource facilities
and/or purchase the electrical output from Third Party alternative resource
facilities located in IID's service area.
2.2 Edison and the Third Parties require transmission service from IID
to deliver the output from such alternative resource facilities to Edison's
electrical system.
2.3 In a Letter Agreement executed on November 22, 1983, the Parties
agreed to establish an intertie connecting the Parties' electrical systems to
facilitate exchanges of power. The Parties also agreed to develop and execute a
transmission service agreement to provide transmission for Edison's power to its
electrical system over IID's existing or upgraded electrical system.
2.4 In a Letter Agreement executed on December 7, 1982, the Parties
agreed to develop certain transmission facilities at 230 kilovolts to provide
for the export of alternative resource facilities electrical output from the
Imperial Valley to Edison's electrical system.
2.5 Edison desires to purchase transmission service for the electrical
output from the alternative resource facilities and IID is willing to sell said
service to Edison.
3. AGREEMENT: The Parties agree as follows:
4. DEFINITIONS: The following terms, when used herein with initial
capitalization, whether in the singular or the plural, shall have the meanings
specified:
4.1. Agreement: This "IID-Edison Transmission Service Agreement for
Alternative Resources" between Southern California Edison Company and Imperial
Irrigation District, and all Exhibits, as such Agreement may subsequently be
amended.
4.2 Authorized Representative: The representative of a Party
designated in accordance with Section 12.
4.3 Blythe Substation: Western's electrical 161 kilovolt (kV)
substation at Blythe, California where IID's existing 161 kV "F" transmission
line terminates.
4.4 Coachella-Mirage Line: Approximately 20.6 miles of 230 kV
transmission line that IID shall cause to be constructed and that shall be owned
by IID. Such line is to
2
be constructed between Coachella Valley Substation and Mirage Substation. The
line is anticipated to be in operation on or before June 1, 1986, or as soon
thereafter as practicable.
4.5 Coachella Valley Substation: IID's electrical substation located
within its Control Area and scheduled to be a terminal point for the Coachella-
Mirage Line.
4.6 Control Area: All or part of a Party's electrical generation
resources, transmission facilities and distribution facilities, or a combination
thereof with those of other utilities, agencies or poo1s to which a common
automatic generation control scheme is applied.
4.7 Date of Initial Service: The date when the Plant output is first
available for delivery to Edison and as provided to IID pursuant to Section 5.2.
Such date shall be deemed to be May 1, 1986, for the Plants specified in
Exhibits II, III, and IV.
4.8 Mirage Substation: Edison's electrical 230/115/92 kV substation
located approximately eight miles west of the City of Indio and one and one-half
miles north of Interstate Highway 10 where the Points of Interconnection are
located and where the Coachella-Mirage Line terminates.
4.9 Normal Transmission Capacity: The maximum electrical power transfer
ability, expressed in megawatts (MW), available to IID to transmit IID's
electrical power and to provide the transmission service. Such transfer ability,
as determined by IID, in its
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sole judgment, shall be consistent with prudent operating procedures and with
generally-accepted engineering and operating practices in the electrical
utility industry.
4.10 Operating Transmission Capability: The maximum electrical power
transfer ability, expressed in megawatts (MW), available to IID at any given
time to transmit IID's electrical power and to provide the transmission service.
Such transfer ability shall be as determined by IID in its sole judgment, may
vary from time-to-time depending on system conditions, and shall be consistent
with prudent operating procedures and generally-accepted engineering and
operating practices in the electrical utility industry.
4.11 Plant(s): The electrical generating alternative resource
facilities developed by Edison or Third Parties for which IID shall provide
transmission service is specified in Exhibits II, III, IV, V, VI, VII, VIII and
in any subsequent Plant Amendment(s).
4.12 Plant Amendment(s): The agreement(s) reached by the Parties, as
amendments to this Agreement, for transmission service to be provided by IID for
each Plant added by Edison or for Edison's account subsequent to the execution
of this Agreement.
4.13 Plant Connection Agreement(s): The agreement(s) between IID and
Third Parties or Edison providing for the connection of the Plant(s) to IID's
electrical system as specified in Exhibits II, III, IV, V, VI, VII, VIII and in
any subsequent Plant Amendment(s).
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4.14 Point of Delivery: The Points of Interconnection, Blythe
Substation or other points as agreed to by the Authorized Representatives as
delivery points and as specified in Exhibits II, III, IV, V, VI, VII, VIII and
in any subsequent Plant Amendments.
4.15 Points of Interconnection: The 115/92 kV switchrack at the Mirage
Substation site where Edison's 115 kV facilities are attached to IID's 92 kV
facilities or the 230 kV switchrack where Edison's 230 kV facilities shall be
attached to the Coachella-Mirage Line.
4.16 Point of Receipt: The point at which IID receives the electrical
output from each Plant for Edison or for Edison's account, as specified in
Exhibits Il, III, IV, V, VI, VII, VIII and in any subsequent Plant Amendments.
4.17 Third Parties: Developers and/or operators of facilities using
alternative resources including biomas, waste, wind, solar, geothermal and water
to produce electrical energy. Such developers and/or operators are not
signatories to this Agreement.
4.18 Transmission Service Entitlement: The amount of transmission
service, expressed in megawatts (MW), provided by IID to Edison from a Point of
Receipt to the Point(s) of Delivery.
4.19 Western: The United States Department of Energy Western Area
Power Administration.
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5. TERM:
5.1 Unless otherwise agreed to by the Parties, this Agreement shall be
effective upon execution by the Parties and shall remain in effect until the
earlier of December 31, 2015 or the termination date of the last Plant
Connection Agreement.
5.2 The Transmission Service Entitlement to be provided by IID for each
Plant shall be contingent on a Plant Connection Agreement being in effect.
Transmission service shall commence on the Date of Initial Service of such
Plant(s). If not already specified in Section 4.7, Edison's Authorized
Representative shall provide the Date of Initial Service to IID's Authorized
Representative in a thirty (30) days' written notice in advance of the Date of
Initial Service.
6. TRANSMISSION SERVICE:
6.1 Subject to the terms of this Agreement, IID shall provide to Edison
and Edison shall purchase from IID transmission service over IID's transmission
system for the Plant(s) herein.
6.2 The Transmission Service Entitlement for each Plant shall be the
amount either specified In Exhibits II, III, IV, V, VI, VII, VIII and in any
subsequent Plant Amendment(s), or the amount provided to IID's Authorized
Representative by Edison's Authorized Representative in a thirty (30)-day
advance written notice prior to the Date of Initial Service. Except for the
Plants specified in Exhibits II, III and IV, the Transmission
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Service Entitlement to be provided by IID subsequent to the Date of Initial
Service may be adjusted semi-annually until the Plant(s) has/have operated for
two years. Such adjustment shall be made by having Edison's Authorized
Representative give IID'S Authorized Representative a ninety (90)-day advance
written notice as to the adjustment required. At the end or the two-year
operating period for such Plant(s), the Transmission Service Entitlement shall
remain as established or as redetermined by the Authorized Representatives and
shall subsequently be fixed for the remainder of the terms specified in Exhibits
II, III, IV, V, VI, VII, VIII and in any subsequent Plant Amendment(s). The
Transmission Service Entitlement shall not be changed unless otherwise agreed to
by the Authorized Representatives.
6.3 IID reserves the right to interrupt or curtail the transmission
service provided hereunder as follows:
6.3.1 If the Operating Transmission Capability is reduced to less than
normal Transmission Capacity from a Point of Receipt to a Point of Delivery, and
when continuity of service within IID's Control Area is not being jeopardized,
IID may curtail the transmission service currently being provided from such
Point of Receipt to such Point of Delivery, to an amount "A" determined by the
following formula:
A = Operating Transmission Capability x Transmission Service
--------------------------------- Entitlement
Normal Transmission Capacity
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The transmission service for each Plant shall be curtailed by multiplying the
Transmission Service Entitlement in accordance with Exhibits II, III, IV, V, VI,
VII, VIII and in any subsequent Plant Amendments by the same percentage
(expressed as a decimal) as used in the determination of "A". However, any such
curtailment shall occur only after IID has made all reasonable efforts to
eliminate the cause of the reduction in Operating Transmission Capability, and
IID shall then employ reasonable efforts to eliminate expeditiously the cause of
said reduction.
6.3.2 If continuity of service within IID's Control Area is being
jeopardized, as determined by IID in its sole judgment, IID may interrupt or
curtail the transmission service provided hereunder to the extent necessary to
avoid or eliminate such jeopardy; provided, (i) that such interruptions or
curtailments may be made so that IID may fully utilize all generating resources
owned by it or available to it under contract in order to avoid damage to IID's
electrical system caused by overloading, (ii) that no such interruption or
curtailment may be made by IID in order that IID may acquire all or any portion
of Edison's capacity or energy available to Edison under contract without
Edison's prior consent, and (iii) that such interruption or curtailment shall
occur only after IID has made all reasonable efforts to avoid or eliminate such
jeopardy.
6.4 If IID's efforts do not avoid or eliminate such jeopardy, the
Parties shall endeavor to develop some other arrangements to avoid or eliminate
such jeopardy and minimize the effects of IID's interruption or curtailment to
both to Parties' Control Areas.
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6.5 Subject to Section 6.8, and in the event of any curtailments or
interruptions made pursuant to Section 6.3.1 or Section 6.3.2, Edison shall,
immediately after being orally satisfied by IID, reduce its energy schedules by
the amounts requested by IID.
6.6 The transmission service to be provided by IID and purchased by
Edison for each Plant shall not exceed the Transmission Service Entitlement.
6.7 Subject to Section 6.3, IID shall, during the periods that IID has
agreed to provide the transmission service at the specified Transmission Service
Entitlements, accept hourly scheduled energy deliveries at the Point of Receipt
and simultaneously deliver the same amount of energy to Edison or for Edison's
account at the Point(s) of Delivery mutually agreed upon by the Parties'
dispatchers and/or schedulers. Unless otherwise agreed to by the Authorized
Representatives, the total sum of Transmission Service Entitlements to the
Points of Delivery specified below shall not exceed 150 MV. However, in no case
shall the Transmission Service Entitlement to a specified Point of Delivery
exceed the following:
Blythe Substation 161 kV: 110 MV
Mirage Substation 115/92 kV: 35 MW
Mirage Substation 230 kV: 150 MW'
Edison shall provide IID an executed copy of its transmission service
agreement with Western.
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6.8 Hourly scheduled energy deliveries shall be in accordance with the
provisions of this Agreement. The hourly schedules shall conform with the
practices and procedures developed by the Parties' dispatchers and schedulers
and agreed to by the Authorized Representatives. IID shall coordinate the hourly
scheduled energy deliveries from the Plant(s) until such time that dynamic
scheduling may be arranged and procedures for such may be agreed to by the
Authorized Representatives.
7. TRANSMISSION LOSSES:
-------------------
7.1 IID shall determine, by transmission power flow analysis, the
electrical losses (expressed as a percent amount of hourly scheduled energy
deliveries) associated with the electrical output from each Plant. Such analysis
may be performed by IID, at its sole expense, and as deemed necessary by
changing conditions on IID's electrical system. The initial percent amount, for
each Plant, representing the electrical losses as determined herein shall be as
specified in Exhibits II, III, IV, V, VI, VII, VIII and in any subsequent Plant
Amendment(s).
7.2 Unless otherwise agreed to by Edison's and IID's schedulers and
dispatchers, IID shall reduce the amount of all hourly scheduled energy
deliveries to Edison or for Edison's account by the percent amount of such
hourly deliveries for each Plant in accordance with Exhibits II, III, IV, V, VI,
VII, VIII and in any subsequent Plant Amendment(s) plus a transformer loss
percent amount if delivered at the Mirage Substation 115/92 kV switchrack.
10
7.3 It either Party believes that there has been a significant change
in IID's electrical system and the electrical losses associated with any Plant
should be redetermined, either Party's Authorized Representative may submit a
written request ________ the other Party's Authorized Representative that the
electrical losses be redetermined. Following such request, a transmission flow
analysis may be performed by IID as approved by the Authorized Representatives
and paid for by the requesting Party. If the percent amount for electrical
losses is redetermined, such percent amount shall become effective as of the
first day of the month following the date of such redetermination; provided,
that such a redetermination may be no sooner than twelve (12) months after the
most recent redetermination. Any redetermination of electrical losses made
pursuant to this Section 7 shall be based on conditions in existence at the time
of such redetermination.
7.4 Along with the monthly billing pursuant to Section 9.1, for the
transmission service for each Plant, IID shall submit a monthly summary of
hourly scheduled energy deliveries and of electrical losses for each Plant.
8. CHARGES:
8.1 For transmission service provided by IID, Edison shall pay IID at
an initial rate of $1.14 per kilowatt per month for transmission service over
IID's 92 kV-161 kV- 230 kV transmission system plus the appropriate initial rate
specified in Exhibit I.B for transmission service over IID's 34.5 kV
subtransmission system as applicable. The total
11
charge for transmission service shall be determined by the sum of the products
of such applicable rates times the Transmission Service Entitlements. The
initial rate for the 92 kV-161 kV-230 kV transmission system and the initial
rate for the 34.5 kV subtransmission system has been determined by IID pursuant
to the methodologies specified in Exhibit I.A and Exhibit I.B respectively. Any
specific facility charge to the Third Parties or to Edison for connecting the
Plant(s) to the IID transmission system(s) shall be included only in the Plant
Connection Agreement(s) between IID and the Third Parties or Edison.
8.2 Both the 92 kV-161 kV-230 kV transmission and 34.5 kV
subtransmission system rates shall be reviewed annually and may be revised. Such
review and revision, if necessary, shall commence effective January 1, 1986. Any
revision of the rates shall be based on the methodologies in Exhibit I.A-2 and
Exhibit I.B.A and on the conditions in existence at the time of the revision.
Edison shall have the right to review any exhibits or work papers prepared by
IID to revise the rates prior to the effective date(s) of the revision.
8.3 An initial monthly scheduling fee, as specified in Exhibits II,
III, IV, V, VI, VII, VIII and in any subsequent Plant Amendment(s), shall be
paid by Edison to IID for those months in which there were scheduled energy
deliveries from the Plant(s). The initial scheduling fee has been determined by
IID pursuant to the methodology specified in Exhibit I.C. The scheduling fee
shall be reviewed annually and may be revised. Such
12
review and revision, if necessary, shall commence effective January 1, 1986. Any
revision of the scheduling fee shall be based on the methodology in Exhibit I.C
and on the conditions in existence at the time of the revision. Edison shall
have the right to review any exhibits or work papers prepared by IID to revise
the scheduling fee prior to the effective date of the revision.
9. BILLING AND PAYMENT:
-------------------
9.1 IID shall render bills to Edison, beginning in the month of the
Date of Initial Service, on or before the fifteenth (15th) day of each month for
the transmission service to be provided during the month. Edison shall pay such
bills within twenty (20) days after receipt thereof.
All payments by Edison shall be sent to:
Imperial Irrigation District
c/c Manager, Finance & Accounting
P.O. Box 937
Imperial, CA 92251
All ▇▇▇▇▇▇▇▇ by IID shall be sent to:
Southern California Edison Company
c/o Manager of Cogeneration and Small Power Development
P.O. Box 800
Rosemead, CA 91770
13
9.2 Either Party's Authorized Representative may at any time, by
advance written notice to the other Party's Authorized Representative, change
the address to which payments or ▇▇▇▇▇▇▇▇ shall be sent.
9.3 Bills which are not paid in full by said due date shall thereafter
bear an additional charge of one and one-half percent (1 1/2%) per month, or the
maximum legal rate of interest, whichever is less, compounded monthly on the
unpaid amount prorated by days from the due date until payment is received by
IID.
9.4. In the event any portion of any bill is disputed, the disputed
amount shall be paid when due under protest. If the protested portion of the
payment is found to be incorrect by the Authorized Representatives, the disputed
amount shall be paid by IID to Edison, including interest at the rate of 1-1/2%
per month, or the maximum legal rate, whichever is less, compounded monthly from
the date of payment by Edison to the date the refund check or adjusted bill is
received by Edison.
9.5 For a fractional part of a calendar month at the beginning or end
of the period for which the transmission service is provided hereunder, the
charge pursuant to Section 8.1 shall be proportionately adjusted by the ratio of
days that service is furnished by IID to Edison during such month to the total
number of days in such month.
9.6 The charge for the transmission service pursuant to Section 8.1
shall be proportionately reduced to the extent the duration of interruptions or
curtailments of the
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transmission service which may occur pursuant to Section 6.3.2 exceed a
cumulative total of twenty-four (24) hours during any calendar month based on
730 hours per month representing the full transmission service charge. The
amount of such prorata reduction in any month shall reflect the duration and
amount of such interruptions or curtailments which exceed said cumulative 24
hours. Such prorata reduction shall be reflected as a credit to Edison as soon
as possible in a subsequent monthly bill.
9.7 The charge for the transmission service shall not be reduced if IID
can deliver, but Edison cannot receive the hourly scheduled energy deliveries
independent of the duration of time this condition exists.
10. LIABILITY:
10.1 Except for any loss, damage, claim, cost, charge or expense
resulting from Willful Action, neither Party, its directors or other governing
body, officers or employees shall be liable to the other Party for any loss,
damage, claim, cost, charge, or expense of any kind or nature incurred by the
other Party (including direct, indirect or consequential loss, damage, claim,
cost, charge or expense; and whether or not resulting from the negligence of a
Party, its directors or other governing body, officers, employees or any person
or entity whose negligence would be imputed to such Party) from engineering,
repair, supervision, inspection, testing, protection, operation, maintenance,
replacement, reconstruction, use or ownership of such Party's electrical system
in connection with implementation of this Agreement. Except for any loss,
damage, claim, cost, charge or
15
expense resulting from Willful Action, each Party releases the other Party, its
directors or other governing body, officers and employees from any such
liability.
10.2 Except for liability resulting from Willful Action of the other
Party, a Party whose electrical customer shall make a claim or bring an action
for any death, injury, loss or damage arising out of delivery of, interruptions
to or curtailment of electrical service to such customer caused by performance
or nonperformance of a Party's obligations hereunder shall indemnify and hold
harmless the other Party, its directors or other governing body, officers and
employees from and against any liability for such death, injury, loss or damage.
As used in this Agreement, the term "electrical customer" shall mean an
electrical consumer, except an electrical utility system to whom power is
delivered for resale.
10.3 For the purpose of this Section 10, Willful Action shall be
defined as action taken or not taken by a Party at the direction of its
directors or other governing body, officers or employees having management or
administrative responsibility affecting its performance under this Agreement, as
follows:
10.3.1 Action which is knowingly or intentionally taken or failed to be
taken with conscious indifference to the consequences thereof or with intent
that injury or damage would result or would probably result therefrom.
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10.3.2 Action which has been determined by final arbitration award or
final judgment or judicial decree to be a material default under this Agreement
and which occurs or continues beyond the time specified in such arbitration
award or judgment or judicial decree for curing such default or, if no time to
cure is specified therein, occurs or continues thereafter beyond a reasonable
time to cure such default.
10.3.3 Action which is knowingly or intentionally taken or not taken
with the knowledge that such action taken or not taken is a material default
under this Agreement.
10.4 Willful Action does not include any act or failure to act which
is merely involuntary, accidental or negligent.
10.5 The phrase "employees having management or administrative
responsibility", as used in Section 10.3, means the employees of a Party who are
responsible for one or more of the executive functions of planning, organizing,
coordinating, directing, controlling and supervising such Party's performance
under this Agreement with responsibility for results.
11. AUDITING:
11.1 IID shall make its books, records, and other supporting
information, as requested, available to Edison or to Edison's designated
contracted representative(s) with a CPA firm, for the purpose of auditing any
charges or accounts to be kept by IID
17
hereunder. All such audits shall be undertaken at reasonable times and in
conformance with generally-accepted auditing standards.
11.2 If as a result of such audits Edison believes its charges or
accounts should be adjusted, the findings shall be presented to the Authorized
Representatives. If the Authorized Representatives agree that any audit finding
should result in a revision of charges or accounts, such revisions shall be
retroactive to the first billing for such charges and accounts and shall be made
as soon as practical after determination.
11.3 The amount of any unresolved dispute shall accrue interest at the
rate of one and one-half percent (1 1/2%) per month, or the maximum legal rate,
whichever is less, compounded monthly for any amount of money ultimately
refunded to Edison.
12. AUTHORIZED REPRESENTATIVES: Within thirty (30) calendar days after
the date of execution of this Agreement, each Party shall designate by written
notice to the other Party a representative who is authorized to act on its
behalf in the implementation of' this Agreement. Either Party may at any time
change the designation of its Authorized Representative by written notice to the
other Party.
13. NO DEDICATION OF FACILITIES: Any undertaking by one Party to the
other Party under any provision of this Agreement shall not constitute the
dedication of the system or any portion thereof of the Party to the public or to
the other Party, and it is
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understood and agreed that any such undertaking under any provision of this
Agreement by a Party shall cease upon the termination of its obligations
hereunder.
14. NON-WAIVER: None of the provisions of this Agreement shall be
considered waived by either Party except when such waiver is given in writing.
The failure of either Party to insist in any one or more instances upon strict
performance of any of the provisions of this Agreement or to take advantage of
arty of its rights hereunder shall not be construed as a waiver of any such
provisions or the relinquishment of any such rights for the future, but the same
shall continue and remain in full force and effect.
15. NO THIRD PARTY RIGHTS: The Parties do not intend to create rights
in or to grant remedies to any ▇▇▇▇ Party or others as a beneficiary of this
Agreement or of any duty, covenant, obligation or undertaking established
hereunder.
16. UNCONTROLLABLE FORCES: Neither Party shall be considered to be in
default in the performance of any of its obligations under this Agreement where
a failure of performance shall be due to an uncontrollable force. The term
"uncontrollable force" shall mean any cause beyond the control of the Party
affected including, but not restricted to, failure of or threat of failure of
facilities which have been maintained in accordance with generally-accepted
engineering and operating practices in the electrical utility industry, flood,
drought, earthquake, tornado, storm, fire, pestilence, lightning and other
natural catastrophes, epidemic, war, riot, civil disturbance or disobedience,
strike, labor
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dispute, labor or material shortage, sabotage, government priorities and
restraint by court order or public authority (whether valid or invalid) and
action or nonaction by or inability to obtain or keep the necessary
authorizations or approvals from any governmental agency or authority, which by
exercise of due diligence such Party' could not reasonably have been expected to
avoid and which by exercise of due diligence it has been unable to overcome.
Nothing contained herein shall be construed as to require a Party to settle any
strike or labor dispute in which it may be involved. Either Party rendered
unable to fulfill any of its obligations under this Agreement by reason of an
uncontrollable force shall give prompt written notice of such fact to the other
Party and shall exercise due diligence to remove such inability with all
reasonable dispatch.
17. ASSIGNMENTS:
17.1 Any assignment by Edison of its interest in this Agreement which
is made without the written consent of IID shall not relieve Edison from its
primary liability for any of its duties and obligations hereunder, and in the
event of any such assignment Edison shall continue to remain primarily liable
for payment of any and all money due IID hereunder and for the performance and
observance of all other covenants, duties and obligations to be performed and
observed hereunder by it to the same extent as though no assignment has been
made.
17.2 Whenever an assignment of Edison's interest in this Agreement is
made with the written consent of' IID, Edison's assignee shall expressly assume
in writing the duties
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and obligations hereunder of Edison and, within thirty (30) days after any such
assignment and assumption of duties and obligations, Edison shall furnish or
cause to be furnished to IID a true and correct copy of such assignment and
assumption of duties and obligations.
18. GOVERNING LAW: This Agreement shall be interpreted, governed by
and construed under the laws of the State of California or the laws of the
United States, as applicable.
19. NOTICES: Any notice, demand or request provided for in this
Agreement, or served, given or made in connection with it, shall be in writing
and shall be deemed properly served, given or made or delivered in person or
sent by United States mail, postage prepaid, to the persons specified below
unless otherwise provided for in this Agreement:
Imperial Irrigation District
c/a General Manager
P. 0. Box 937
Imperial, California 92551
Southern California Edison Company
c/o Secretary
P.0. Box 800
Rosemead, California 91770
Either Party may at any time, by notice to the other Party, change the
designation or address of the person so specified as the one to receive notices
pursuant to this Agreement.
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20. SIGNATURE CLAUSE: The signatories hereto represent that they have
been appropriately authorized to enter into this IID-Edison Transmission Service
Agreement for Alternative Resources on behalf of the Party for whom they sign.
This Agreement is hereby executed as of the 26 day of September, 1985.
IMPERIAL IRRIGATION DISTRICT
By: /s/ ▇▇▇▇▇ ▇. ▇▇▇▇▇
-----------------------------
Name: ▇▇▇▇▇ ▇. ▇▇▇▇▇
President, Pro Tem Board of Directors
SOUTHERN CALIFORNIA EDISON COMPANY
By: /s/ ▇▇▇▇▇▇ ▇. ▇▇▇▇▇, ▇▇.
-----------------------------
Name: ▇▇▇▇▇▇ ▇. ▇▇▇▇▇, ▇▇.
Vice President
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EXHIBIT I
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DEVELOPMENTS AND METHODOLOGIES FOR THE TRANSMISSION AND SUBTRANSMISSION SERVICE
CHARGES AND SCHEDULING FEE.
-------------------------------------------------------------------------------
EXHIBIT I.A
-----------
DEVELOPMENT AND METHODOLOGY FOR THE 92 kV-161 kV-230 kV TRANSMISSION SERVICE
CHARGE.
EXHIBIT I.B
-----------
DEVELOPMENT AND METHODOLOGY FOR THE 34.5 kV SUBTRANSMISSION SERVICE CHARGE.
EXHIBIT I.C
-----------
METHODOLOGY AND CALCULATION OF SCHEDULING FEE.
EI-1
EXHIBIT I.A
-----------
DEVELOPMENT AND METHODOLOGY FOR THE 92 kV - 161 kV - 230 kV
TRANSMISSION SERVICE CHARGE
-----------------------------------------------------------
EI.A-1 Development
------------------
Plant Investment
----------------
Transmission @ 12/31/83
OC (2)......................................... $20,700,415
RCN (3)........................................ 88,300,000
Adjusted Investment
-------------------
Weighted Plant (4)............................. 40,980,291
Plant Additions in 1984........................ 4,111,000
General Plant (Allocated) (5).................... 120,625
M&S (Allocated) (6).............................. 782,629
----------
Total Adjusted Investment (TAI).................. $45,994,545
Annual Cost
-----------
Fixed Cost @ 13.53% x (TAI) (1).................. $ 6,223,062
Trans. ▇&▇ (Allocated) (7)....................... 764,058
A&G (Allocated) (8).............................. 332,847
-----------
Total Annual Cost ............................... $ 7,309,967
Annual Peak Load - (kW) (Includes Wheeling of
63,000 kW) ....................................... 432,000
Cost Per kW Per Year............................... $ 16.92
Cost Per kW Per Month .............................. $ 1.41
-----
-----
EI.A-2 Methodology
------------------
(1) Fixed cost @ 13.53% based upon 10.41% interest rate, 33-year
amortization, and 1.25 coverage. This rate is based on the
average interest rate for the previous 12 months as obtained
from the "▇▇▇▇▇▇▇ ▇▇▇▇▇ 500 Municipal Bond Index Electric -
Retail".
(2) OC = Original Cost; see under Original Cost, "Transmission
Plant, Transmission" EI-4
(3) RCN = Reproduction Cost New; see under "Total-RCN"-EI-5
(4) Weighted Plant = 70% OC + 30% RCN
EI-2
(5) General Plant (Allocated) =
General Plant X Trans. O&M (Allocated)
----------------------------------
(Prod. O&M Exc. Fuel) +
(Dist. O&M) + (Trans. O&M)
+ (Dispatching) + (Customer Acctg.
and Services)
= $1,526,849 X $764,058
----------------------------------
$3,085,080 + $4,080,868 + $694,545
+ $189,540 + $1,621,252
= $1,526,849 X $764,058 = $120,625
---------- ========
$9,671,285
(6) M&S (Allocated) =
M&S X Transmission OC
------------------
Total Elect. Plant
= $6,151,304 X $20,700,415 = $782,629
------------ ========
$162,700,978
(7) Trans. O&M (Allocated) =
Trans. O&M X Transmission OC + Dispatching
-----------------
Total Trans Plant
= $694,545 X $20,700,415 + $189,540
-----------
$25,025,093
= $764,058
========
(8) A&G (Allocated) =
A&G X Trans. O&M (Allocated)
--------------------------------------
(Prod. O&M Exc. Fuel) + (Dist. (O&M)
+(Trans. O&M) + (Dispatching) +
(Customer Acctg. and Services)
= $4,086,530 X $764,058 = $322,847
-------------- ========
$9,671,285
EI-3
EI-4
IMPERIAL IRRIGATION DISTRICT
IID-Edison Transmission ----------------------------
Service Agreement for ELECTRIC PLANT INVESTMENT
Alternative Resources -------------------------
12-31-83
--------
Original Reserved for Depreciated
Cost Depreciation Value
---------- ------------ ------------
Production Plant:
----------------
Steam $ 27,669,266 $18,714,813 $ 8,954,453
Hydro 20,837,053 12,515,654 8,321,399
Diesel 2,192,176 1,678,426 513,750
Gas turbines 21,254,581 4,526,058 16,728,523
Heber geothermal 73,884 12,245 61,639
*Other production
------------ ----------- -----------
Total production plant 72,026,960 37,447,196 34,579,764
------------ ----------- -----------
Transmission Plant:
------------------
Transmission 20,700,415 11,847,260 8,853,155
Subtransmission 4,324,678 1,727,232 2,597,446
------------ ----------- -----------
Total transmission plant 25,025,093 13,574,492 11,450,601
------------ ----------- -----------
Distribution Plant:
------------------
Land and land rights 401,433 401,433
Structures and improvements 664,823 328,992 335,831
Station equipment 11,929,448 5,082,909 6,846,539
Poles, towers and fixtures 11,485,005 3,630,291 7,854,714
Overhead conductors and devices 9,389,058 4,708,089 4,680,969
Underground conduit 316,690 78,540 238,150
Underground conductors and devices 4,145,254 703,256 3,441,998
Line transformers 14,523,770 5,878,024 8,645,746
Services 3,386,047 1,825,151 1,560,896
Meters 4,247,559 1,542,261 2,705,298
Street lighting and signal system 2,227,858 963,106 1,264,752
------------ ----------- -----------
Total distribution plant 62,716,945 24,740,619 37,976,326
------------ ----------- -----------
General plant 1,526,849 699,191 827,658
Intangible plant 49,379 49,379
Donations in aid of construction -
P.W.A. Grant 2,080,920 [ 2,080,920]
Contributions in aid of construction 1,590,228 [ 1,590,228]
------------ ----------- -----------
Total electric plant in service 161,345,226 80,132,646 81,212,550
------------ ----------- -----------
Electric plant acquisition adjustment 719,334 719,334
Electric plant held for future use 636,418 318,712 317,706
------------ ----------- -----------
Total electric plant $162,700,978 $81,170,692 $81,530,286
============ =========== ===========
Materials and supplies $ 6,151,304
============
[ ] Deductions
* Included in Gas Turbines
EI-4
REPRODUCTION COST AS OF 12/31.83
EI-5
IID-Edison Transmission (Costs In Millions Of Dollars)
Service Agreement for ORIGINAL NET
Alternative Resources YEAR COST ADDITIONS HWI TRANSLATOR RCN
-------------------- --------------- --------------- ------------- ---------------- -------------
1938 0.15 0.15 22 11.55 1.73
1939 0.24 0.09 22 11.55 1.04
1940 0.26 0.02 22 11.55 0.23
1941 0.26 0.00 23 11.04 0.00
1942 0.55 0.29 25 10.16 2.95
1943 1.78 1.23 25 10.16 12.50
1944 2.05 0.27 25 10.16 2.74
1945 1.91 -0.14 26 9.77 -1.37
1946 1.85 -0.06 29 8.76 -0.53
1947 2.13 0.28 34 7.47 2.09
1948 2.32 0.19 37 6.86 1.30
1949 3.45 1.13 38 6.68 7.55
1950 4.35 0.90 40 6.35 5.72
1951 4.49 0.14 45 5.64 0.79
1952 6.07 1.58 46 5.52 8.72
1953 6.23 0.16 49 5.18 0.83
1954 6.79 0.56 50 5.08 2.84
1955 7.83 1.04 52 4.88 5.08
1956 8.36 0.53 56 4.54 2.40
1957 9.94 1.58 57 4.46 7.04
1958 10.16 0.22 59 4.31 0.95
1959 10.64 0.48 60 4.23 2.03
1960 10.95 0.31 60 4.23 1.31
1961 11.03 0.08 59 4.31 0.34
1962 11.76 0.73 59 4.31 3.14
1963 11.80 0.04 59 4.31 0.17
1964 12.00 0.20 61 4.16 0.83
1965 12.08 0.08 64 3.97 0.32
1966 12.36 0.28 67 3.79 1.06
1967 12.46 0.10 70 3.63 0.36
1968 13.10 0.64 73 3.48 2.23
1969 13.33 0.23 78 3.26 0.75
1970 14.22 0.89 83 3.06 2.72
1971 14.43 0.21 89 2.85 0.60
1972 14.47 0.04 93 2.73 0.11
1973 14.59 0.12 100 2.54 0.30
1974 15.19 0.60 124 2.05 1.23
1975 15.21 0.02 145 1.75 0.04
1976 15.32 0.11 158 1.61 0.18
1977 15.59 0.27 172 1.48 0.40
1978 15.71 0.12 174 1.46 0.18
1979 15.85 0.14 190 1.34 0.19
1980 16.14 0.29 211 1.20 0.35
1981 18.18 2.04 230 1.10 2.25
1982 20.08 1.90 245 1.04 1.97
1983 20.70 0.62 254 1.00 0.62
--------------- --------------- ------------- ---------------- -------------
TOTAL 20.70 20.70 254 4.27 88.30
(1) Original Cost As Of December 31 Of Each Year Was Obtained From IID Annual Reports And
Includes 92 kV And 161 kV Transmission Plant Investment.
(2) ▇▇▇▇▇-▇▇▇▇▇▇▇ Index For Total Transmission Plant For The Pacific Region Was Utilized To
Compute The RCN.
(3) RCN - Net Additions * HWI Translator EI-5
EXHIBIT I.B
-----------
DEVELOPMENT AND METHODOLOGY FOR THE 34.5 kV
SUBTRANSMISSION SERVICE CHARGE
--------------------------------------------
EI.B-1 DEVELOPMENT OF SERVICE CHARGES-BRAWLEY
GEOTHERMAL PLANT UNIT NO. 1
--------------------------------------
▇. ▇▇▇▇▇▇▇ to Rio Vista
--------------------
Miles x OC = 2.8 mi x $7,291/mi = $20,415
AFC = .1353 x $20,415 = $2,762 TL = 21,000 kW
O&M = .03 X 20,415 = 612 $/kW-yr = $0.1704
A&G = .01 X 20,415 = 204 $/kW-mo = $0.0142
------ =======
$/yr. = $3,578
B. Rio Vista to Brawley
--------------------
Miles x OC = 1.74 mi x $7,2191/mi = $12,686
AFC = .1353 x $12,686 = $1,716 TL - 31,750 kW
O&M = .03 x 12,686 = 381 $/kW-yr = $0.0700
A&G = .01 x 12,686 = 127 $/kW-mo = 0.0058
------ =======
$/yr. = $2,224
▇. ▇▇▇▇▇▇▇ to ▇▇▇▇▇▇▇▇
-------------------
Miles x OC = 0.96 mi x $7,291/mi = $6,999
AFC = .1353 x $6,999 = $ 947 TL = 53,000 kW
O&M = .03 x 6,999 = 210 $/kW-yr = $0.0232
A&G - .01 x 6,999 = 70 $/kW-mo = $0.0019
------ =======
$/yr. = $1,227
SUMMARY OF CHARGES
------------------
A + B + C = $ (0.0142 + 0.0058 + 0.0019) /kW-mo.
= $0.0219/kW mo.
Rounded to: $0.022/kW-mo.
=============
EI-6
EI.B-2 DEVELOPMENT OF SERVICE CHARGES - SALTON SEA
GEOTHERMAL PLANT UNIT NO. 1
-------------------------------------------
A. SALTON SEA TO CALIPATRIA
------------------------
Miles x OC = 10.8 mi x $7,291/mi = $78,743
AFC = .1353 x $78,743 = $10,654 TL = 9,000 kW
O&M = .03 X $78,743 = 2,362 $kW-yr = $1.5337
A&G = .01 X $78,743 = 787 $kW-mo = $0.1278
------- =======
$/yr. = $13,803
B. Calipatria to Brawley
---------------------
Miles x OC = 9.9 mi x $7,291/mi = $72,181
AFC = .1353 x $72,181 = $ 9,766 TL = 15,000 kW
O&M = .03 x 72,181 = 2,165 $/kW-yr = $0.8435
A&G = .01 x 72,181 = 722 $/kW-mo = $0.0703
------- =======
$/yr. = $12,653
▇. ▇▇▇▇▇▇▇ to Rio Vista
--------------------
Miles x OC = 2.8 mi x $7,291/mi = $20,415
AFC = .1353 x $20,415 = $ 2,762 TL = 21,000 kW
O&M = .03 x 20,415 = 612 $/kW-yr = $0.1704
A&G = .01 x 20,415 = 204 $/kW-mo = $0.0142
-------- =======
$/yr. = $3,578
D. Rio Vista to Brawley
--------------------
Miles x OC = 1.74 mi x $7,291/mi = $12,686
AFC = .1353 x $12,686 = $1,716 TL = 31,750 kW
O&M = .03 x 12,686 = 381 $/kW-yr = $0.0700
A&G = .01 x 12,686 = 127 $/kW-mo = 0.0058
------- =======
$/yr. = $2,224
▇. ▇▇▇▇▇▇▇ to ▇▇▇▇▇▇▇▇
-------------------
Miles x OC = 0.96 mi x $7,291/mi = $6,999
AFC = .1353 x $6,999 = $ 947 TL = 53,000 kW
O&M = .03 x 6,999 = 210 $/kW-yr = $0.0232
A&G = .01 x 6,999 = 70 $/kW-mo = $0.0019
------- =======
$/yr. = $1,227
SUMMARY OF CHARGES
------------------
A + B + C + D + E =
$ (0.1278 + 0.0703 + 0.0142 + 0.0058 + 0.0019)/kW mo.
= $0.2200/kW-mo.
Rounded to: $0.22/kW-mo.
===========
EI-7
EI.B-3 DEVELOPMENT OF SERVICE CHARGES FOR MAGMA
EAST MESA GEOTHERMAL PLANT UNIT NO. 1
----------------------------------------
A. East Mesa to Magma (TAP)
------------------------
Miles x OC = 6.37 mi x $7,291/mi = $46,444
AFC = .1353 x $46,444 = $6,284 TL = 5,000 kW
O&M = .03 x 46,444 = 1,393 $/kW-yr = $1.6282
A&G = .01 x 46,444 = 464 $/kW-mo = $0.1357
------ =======
$/yr. = $8,141
B. Magma (Tap) to Holtville
------------------------
Miles x OC = 4.33 mi x $7,291/mi = $31,570
AFC = .1353 x $31,570 = $4,271 TL = 5,700 kW
O&M = .03 x 31,570 = 947 $/kW-yr = $0.9709
A&G - .01 x 31,570 = 316 $/kW-mo = $0.0809
------ =======
$/yr. = $5,534
SUMMARY OF CHARGES
------------------
A + B = $(0.1357 + 0.0809) /kW mo.
= $0.2166/kW-mo.
Rounded to: $0.22/kW-mo.
===========
EI-8
EI.B.A METHODOLOGY FOR 34.5 kV SUBTRANSMISSION SERVICE CHARGE
------------------------------------------------------
(1) Original Cost (OC): OC = Curr. $/mi x 1964 HW
-------
1984 HW
HW=▇▇▇▇▇-▇▇▇▇▇▇▇ Index for Total Transmission Plant
For The Pacific Region
Curr. $/mi - $30,000/mi
1964 HW = 61
1984 HW 251
OC = $30,000/mi x 61 = $30,000/mi x 0.2430
-----
251 = $7291/mi
(2) O&M = 3% of OC
(3) A&G = 1% of OC
(4) Annual Fixed Cost (AFC) = 13.53% of OC; 13.53% is as
defined in EI.A-2(1)
(5) Transmission Loading (TL) = absolute value of
line loadings.
(6) $/kW-yr = $/yr divided by TL
(7) For mileages see EI-10
EI-9
EI-10
ONE LINE DIAGRAM OF SUBTRANSMISSION PATH
FOR EXISTING GEOTHERMAL UNITS
[Graphic: Simplified IID Transmission Diagram]
NOTE: DIAGRAM DEPICTS SHORTEST 34.5 KV PATH TO 92 KV TRANSMISSION-NETWORK
LOADS REPRESENT 1984 ESTIMATED SUMMER PEAK LOADS
EI-10
EXHIBIT I.C
METHODOLOGY AND CALCULATION OF SCHEDULING FEE
----------------------------------------------------
ANNUAL DETERMINATION
OF
IID SCHEDULING FEES
---------------------
IID, prior to January 1 of each year, will calculate monthly fees for
scheduling services related to Alternative Energy Resources and transactions
with other utilities as follows:
A. An appropriate number of scheduling units will be assigned to every
IID resource, Alternative Energy Resource, and transaction with other
utilities. The number of scheduling units assigned to each resource
and/or transaction will depend upon the total daily number of
functions and therefore, estimated time required to schedule the
resource and/or transaction. This estimate will be directly related to
the complexity of the scheduling service being provided. Table 1
provides an example of how the total scheduling units will be
determined for the 1985 IID system.
B. The expenses related to dispatching and scheduling services will be
equal to the sum of the following:
1. FPC Account 556, as provided by the IID budget for the
appropriate year, and
2. A portion of the annual expenses related to the SCADA and AGC
systems.
The portion of the annual expenses related to the SCADA and AGC systems
will be determined by multiplying the levelized debt service payments
for the systems by the percentage that FPC Account 556 is of the total
of FPC Accounts 556, 561 and 581. Table 2 provides an example of the
calculations involved with this step.
C. The annual scheduling fee per scheduling unit will be determined by
dividing the expenses related to scheduling found in Step 8 by the
total scheduling units from Step A. The per unit fee will then be
multiplied by the number of scheduling units assigned to each resource
and/or transaction to develop an appropriate annual scheduling fee for
that resource and/or transaction. The monthly scheduling fee will then
be calculated by dividing the annual fee by 12. Table 3 provides an
example of this step for 1985.
7-26-85
EI-11
Table 1
Imperial Irrigation District
SCHEDULING FEE METHODOLOGY
DETERMINATION OF TOTAL SCHEDULING UNITS
---------------------------------------
Hours Payback/ On AGC OFF
Energy Capacity Variable Banking Prescheduling System System
(X=2) (X=2) (X=1) (X=2) (X=1) (X=1) (X=1)
------ -------- -------- -------- ------------- -------- --------
IID's Generating Units:
Pilot Knob........................ x x x x
Drop #1 .......................... x x x x
Drop #2 .......................... x x x x
Drop #3 .......................... x x x x
Drop #4 .......................... x x x x
Drop #5 .......................... x x x x
East Highline .................... x x x x
Turnip & Double ▇▇▇▇ ............. x x x x
E1 Centro Unit #3 ................ x x x x
E1 Centro Unit $4 ................ x x x x
Coachella Units #1 & #2........... x x x x
Coachella Units #3 & #4........... x x x x
Rockwood ......................... x x x x
Brawley .......................... x x x x
Brawley Diesels .................. x x x x
Alternative Energy Resources:
Salton Sea ....................... x x x x x x
Magma (East Mesa) ................ x x x x x x
Brawley .......................... x x x x x x
Dravo ............................ x x x x x x
Heber Binary ..................... x x x x x x
Transactions with Other Utilities:
DOE .............................. x x x x x
EPE .............................. x x x x x
SCE .............................. x x x x x x
SUGAE ............................ x x x x x
APS (▇▇▇▇▇) ...................... x x x x x
SCE GIs (Axis) ................... x x x x x x
APS (Axis) ....................... x x x x x
YCMUA ............................ x x x x x x
Loss Accounting
(X=1) Total
---------------- -----
IID's Generating Units:
Pilot Knob........................ 6
Drop #1 .......................... 6
Drop #2 .......................... 6
Drop #3 .......................... 6
Drop #4 .......................... 6
Drop #5 .......................... 6
East Highline .................... 6
Turnip & Double ▇▇▇▇ ............. 6
E1 Centro Unit #3 ................ 6
E1 Centro Unit $4 ................ 6
Coachella Units #1 & #2........... 6
Coachelle Units #3 & #4........... 6
Rockwood ......................... 6
Brawley .......................... 6
Brawley Diesels .................. 6
-----
Subtotal ................. 90
Alternative Energy Resources:
Salton Sea ....................... 9
Magma (East Mesa) ................ 9
Brawley .......................... 9
Dravo ............................ x 10
Heber Binary ..................... x 10
-----
Subtotal ................ 47
Transactions with Other Utilities:
DOE .............................. 7
EPE .............................. 7
SCE .............................. 9
SUGAE ............................ x 8
APS (Yucca) ...................... 7
SCE GIs (Axis) ................... 9
APS (Axis) ....................... 7
YCMUA ............................ 7
-----
Subtotal ................ 61
Total Scheduling Units 198
-----
7-24-85
EI-12
Table 2
Imperial Irrigation District
SCHEDULING FEE METHODOLOGY
EXPENSES RELATED TO SCHEDULING
------------------------------
IID 1985 Budget
---------------
FPC Account 556 $158,600 (29.1%)
FPC Account 561 237,500 (43.5%)
FPC Account 581 149,300 (27.4%)
--------
Total $545,400 (100.0%)
SCADA and AGC Systems
---------------------
Total Investment $6,200,000
Annual Expense
6,200,000 x .1170923(1) = $ 725,972
Expenses Related to Scheduling
------------------------------
FPC Account 556 $158,600
29.1% of SCADA and
AGC Systems Annualized
Expense (725,972 x .291) 211,258
--------
Total Expenses Related to
Scheduling $369,858
(1) Capital Recovery Factor determined from levelized debt service
payments of $7,611,000 for $65,000,000 May, 1983 Bond Issue.
7-25-85
EI-13
Table 3
Imperial Irrigation District
SCHEDULING FEE METHODOLOGY
CALCULATION OF SCHEDULING FEE
-----------------------------
Annual Charge Per Scheduling Unit
---------------------------------
Total Expenses Related to Scheduling (From Table 2) $369,858
Total Scheduling Units (From Table 1) 198
--------
Annual Charge per Scheduling Unit (369,858/198) $ 1,868/year
Alternative Energy Resource Scheduling Fee
------------------------------------------
Salton Sea, Magma (East Mesa), Brawley:
Annual Charge (9 Scheduling Units x $1,868) $ 16,812/year
Monthly Charge ($16,812 divided by 12) $ 1,401/month
(1) Bravo and (2) ▇▇▇▇▇ ▇▇▇▇▇▇:
Annual Charge (10 Scheduling Units x $1,868) $18,680/year
(3) Monthly Charge ($18,680 divided by 12) $ 1,557/month
NOTES:
-----
(1) Bravo = Heber Geothermal Company Exhibit V.
(2) Heber Binary - SDG&E Binary Geothermal Unit not included in this IID-Edison
Transmission Service Agreement for Alternative Resources.
(3) Also applies as initial Monthly Fee for Plants in Exhibits VI, VII and
VIII.
7-26-85
EI-14
EXHIBIT V
---------
TRANSMISSION SERVICE
FOR THE HEBER GEOTHERMAL POWER PLAN UNIT NO. 1
----------------------------------------------
EV-1. DESCRIPTION: The Heber Geothermal Power Plant Unit No. 1 at 52 MW
(gross) located in the Heber Known Geothermal Resource Area of the
Imperial Valley.
EV-2. APPLICABILITY: Applicable to the transmission service to be provided by
IID to Edison for transmitting the electrical output from the Heber
Geothermal Plant Unit No. 1 Point of Receipt to the Point(s) of
Delivery.
EV-3. PLANT CONNECTION AGREEMENT: The Heber Geothermal Plant Connection
Agreement to be executed between IID and Heber Geothermal Company.
EV-4. TRANSMISSION SERVICE ENTITLEMENT: 47 MW or the amount provided in
accordance with Section 6.2.
EV-5. POINT OF RECEIPT: Heber Geothermal Power Plant Unit No. 1 Switchyard, 92
kV Bus.
EV-6. POINT(S) OF DELIVERY: Points of Interconnection or Blythe Substation.
EV-7. TERM: The term of the Transmission Service Entitlement for the Heber
Geothermal Power Plant Unit No. 1 shall be effective from the Date of
Initial Service and shall be effective from the Date of Initial Service
and shall terminate on the earliest of: (i) December 31, 2015, or (ii)
twenty-four (24) months from the date Unit No. 1 has ceased to operate
as determined by IID, or (iii) the termination date of the Plant
Connection Agreement, or (iv) the date agreed to by the Authorized
Representative.
EV-8. TRANSMISSION SERVICE CHARGE: $1.41 per kilowatt-month, or as revised in
accordance with Section 8.2, times Transmission Service Entitlement.
EV-9. SCHEDULING FEE: $1557 per month or as revised in accordance with Section
8.3.
EV-10. TRANSMISSION LOSSES: 4.1% or as revised in accordance with Section 7.
EI-18
EXHIBIT VIII
------------
TRANSMISSION SERVICE
FOR THE ORMESA GEOTHERMAL POWER PLANT UNIT NO. 1
------------------------------------------------
EVIII-1. DESCRIPTION: The Ormesa Geothermal Power Plant Unit No. 1 at 30 MW
(gross) located in the East Mesa Known Geothermal Resource Area of the
Imperial Valley.
EVIII-2. APPLICABILITY: Applicable to the transmission service to be provided
by IID to Edison for transmitting the electrical output from the
Ormesa Geothermal Power Plant Unit No. 1 from the Point of Receipt to
the Point(s) of Delivery.
EVIII-3. PLANT CONNECTION AGREEMENT: The Ormesa Geothermal Plant Connection
Agreement to be executed between IID and Ormesa Geothermal.
EVIII-4. TRANSMISSION SERVICE ENTITLEMENT: 24 MW or the amount provided in
accordance with Section 6.2.
EVIII-5. POINT OF RECEIPT: Ormesa Geothermal Power Plant Unit No. 1 Switchyard,
92 kV Bus.
EVIII-6. POINT(S) OF DELIVERY: Points of Interconnection or Blythe Substation.
EVIII-7. TERM: The term of the Transmission Service Entitlement for the Ormesa
Geothermal Power Plan Unit No. 1 shall be effective from the Date of
Initial Service and shall terminate on the earliest of: (i) December
31, 2015, or (ii) twenty-four (24) months from the date Unit No. 1 has
ceased to operate as determined by IID, or (iii) the termination
date of the Plant Connection Agreement, or (iv) the date agreed to by
the Authorized Representatives.
EVIII-8. TRANSMISSION SERVICE CHARGE: $1.41 per kilowatt-month, or as revised
in accordance with Section 8.2, times Transmission Service
Entitlement.
EVIII-9. SCHEDULING FEE: $1557 per month or as revised in accordance with
Section 8.3.
EVIII-10. TRANSMISSION LOSSES: 5.4% or as revised in accordance with Section 7.
EI-21
