Integrated System Rate Schedule Changes, 63969-63978 [E8-25690]
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Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
Any person desiring to intervene or to
protest this filing in accordance with
Rules 211 and 214 of the Commission’s
Rules of Practice and Procedure (18 CFR
385.211 and 385.214). Protests will be
considered by the Commission in
determining the appropriate action to be
taken, but will not serve to make
protestants parties to the proceeding.
Any person wishing to become a party
must file a notice of intervention or
motion to intervene, as appropriate.
Such notices, motions, or protests must
be filed on or before the date indicated
below. Anyone filing a motion to
intervene or protest must serve a copy
of that document on the Applicant. In
reference to filings initiating a new
proceeding, interventions or protests
submitted on or before the comment
deadline need not be served on persons
other than the Applicant.
The Commission encourages
electronic submission of protests and
interventions in lieu of paper, using the
FERC Online links at https://
www.ferc.gov. Persons unable to file
electronically should submit an original
and 14 copies of the intervention or
protest to the Federal Energy Regulatory
Commission, 888 First Street, NE.,
Washington, DC 20426.
This filing is accessible on-line at
https://www.ferc.gov, using the
‘‘eLibrary’’ link and is available for
review in the Commission’s Public
Reference Room in Washington, DC.
There is an ‘‘eSubscription’’ link on the
Web site that enables subscribers to
receive e-mail notification when a
document is added to a subscribed
docket(s). For assistance with any FERC
Online service, please e-mail
FERCOnlineSupport@ferc.gov, or call
(866) 208–3676 (toll free). For TTY, call
(202) 502–8659.
Comment Date: 5 p.m. Eastern Time
November 14, 2008.
Kimberly D. Bose,
Secretary.
[FR Doc. E8–25619 Filed 10–27–08; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
ebenthall on PROD1PC60 with NOTICES
[Docket No. PR09–1–000]
MMP Desoto Pipeline, L.P.; Notice of
Rate Election
Commission’s regulations. DeSoto
proposes to utilize its presently effective
Texas Railroad Commission city-gate
transportation rate for interruptible
transportation service on its Central and
North System pursuant to Section 311 of
the Natural Gas Act. The interruptible
transportation rate for both systems is
20.5 cents/MMBtu plus 0.5 percent fuel
reimbursement.
Any person desiring to participate in
this rate filing must file in accordance
with Rules 211 and 214 of the
Commission’s Rules of Practice and
Procedure (18 CFR 385.211 and
385.214). Protests will be considered by
the Commission in determining the
appropriate action to be taken, but will
not serve to make protestants parties to
the proceeding. Any person wishing to
become a party must file a notice of
intervention or motion to intervene, as
appropriate. Such notices, motions, or
protests must be filed on or before the
date as indicated below. Anyone filing
an intervention or protest must serve a
copy of that document on the Applicant.
Anyone filing an intervention or protest
on or before the intervention or protest
date need not serve motions to intervene
or protests on persons other than the
Applicant.
The Commission encourages
electronic submission of protests and
interventions in lieu of paper using the
‘‘eFiling’’ link at https://www.ferc.gov.
Persons unable to file electronically
should submit an original and 14 copies
of the protest or intervention to the
Federal Energy Regulatory Commission,
888 First Street, NE., Washington, DC
20426.
This filing is accessible on-line at
https://www.ferc.gov, using the
‘‘eLibrary’’ link and is available for
review in the Commission’s Public
Reference Room in Washington, DC.
There is an ‘‘eSubscription’’ link on the
Web site that enables subscribers to
receive e-mail notification when a
document is added to a subscribed
docket(s). For assistance with any FERC
Online service, please e-mail
FERCOnlineSupport@ferc.gov, or call
(866) 208–3676 (toll free). For TTY, call
(202) 502–8659.
Comment Date: 5 p.m. Eastern Time on
Tuesday, November 4, 2008.
October 21, 2008.
Take notice that on October 14, 2008,
MMP Desoto Pipeline, L.P., (Desoto)
filed a Notice of Rate Election pursuant
to section 284.123(b)(1)(ii) of the
Kimberly D. Bose,
Secretary.
[FR Doc. E8–25614 Filed 10–27–08; 8:45 am]
BILLING CODE 6717–01–P
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63969
DEPARTMENT OF ENERGY
Southwestern Power Administration
Integrated System Rate Schedule
Changes
Southwestern Power
Administration, DOE.
ACTION: Notice of Proposed Changes to
Southwestern Power Administration
Rate Schedules and Opportunity for
Public Review and Comment.
AGENCY:
SUMMARY: Due to the omission of the P–
06A Rate Schedule from the Notice of
Proposed Changes to Southwestern
Power Administration Rate Schedules
and Opportunity for Public Review and
Comment published on October 20,
2008 (73 FR 62269), this notice is a
resubmission to include both the P–06A
and the NFTS–06A Rate Schedule
proposals for review and comment.
The Administrator, Southwestern
Power Administration (Southwestern),
has determined that revisions to the
Real Power Losses provisions within
existing rate schedules P–06 and NFTS–
06 are required. Since the proposed rate
schedule revisions are limited only to
Real Power Losses, the net result of the
2006 Integrated System Power
Repayment Studies, which was the basis
for the existing rate schedules, will not
be altered.
Southwestern held several meetings
during FY 2008 with customers to
discuss the proposed rate schedule
revisions and provide opportunity for
input in the development of the final
rate schedules. As a result of these
informal meetings, it was determined
that the revised rate schedule provisions
can provide cost-savings and
operational benefits to Southwestern’s
transmission customers and are
consistent with Federal Energy
Regulatory Commission (FERC) Order
No. 888.
DATES: The consultation and comment
period will begin on the date of
publication of this Federal Register
notice and will end November 28, 2008.
FOR FURTHER INFORMATION CONTACT: Mr.
James K. McDonald, Assistant
Administrator, Office of Corporate
Operations, Southwestern Power
Administration, U.S. Department of
Energy, One West Third Street, Tulsa,
Oklahoma 74103, (918) 595–6690,
jim.mcdonald@swpa.gov.
SUPPLEMENTARY INFORMATION: The U.S.
Department of Energy (DOE) was
created by an Act of the U.S. Congress,
Department of Energy Organization Act,
Public Law 95–91, dated August 4,
1977. Southwestern’s power marketing
activities were transferred from the
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Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
ebenthall on PROD1PC60 with NOTICES
Department of Interior to the DOE,
effective October 1, 1977. Guidelines for
preparation of power repayment studies
are included in DOE Order No. RA
6120.2 entitled Power Marketing
Administration Financial Reporting.
Procedures for Public Participation in
Power and Transmission Rate
Adjustments of the Power Marketing
Administrations are found at Title 10,
part 903, Subpart A of the Code of
Federal Regulations (10 CFR 903).
Procedures for the confirmation and
approval of rates for the Federal Power
Marketing Administrations are found at
Title 18, part 300, Subpart L of the Code
of Federal Regulations (18 CFR 300).
Southwestern markets power from 24
multi-purpose reservoir projects, with
hydroelectric power facilities
constructed and operated by the U.S.
Army Corps of Engineers. These projects
are located in the states of Arkansas,
Missouri, Oklahoma, and Texas.
Southwestern’s marketing area includes
these states plus Kansas and Louisiana.
The costs associated with the
hydropower facilities of 22 of the 24
projects are repaid via revenues
received under the Integrated System
rates, as are Southwestern’s
transmission facilities that consist of
1,380 miles of high-voltage transmission
lines, 24 substations, and 46 microwave
and VHF radio sites. Costs associated
with the Robert D. Willis and Sam
Rayburn Dams, two projects that are
isolated hydraulically, electrically, and
financially from the Integrated System
are repaid by separate rate schedules.
Current and Proposed Real Power
Losses Provisions
The current P–06 and NFTS–06 rate
schedules determine the annual rate for
real power losses based upon the
average of Southwestern’s actual costs
for the purchase of energy to replace
real power losses during the previous
Fiscal Year (October through
September), as reflected in
Southwestern’s financial records.
Customers have the option to either
purchase losses from Southwestern or
elect, on an annual basis, to self-provide
their respective loss energy subject to
certain conditions. Customers who
purchase loss energy from Southwestern
are assessed a monthly charge equal to
the product of Southwestern’s theneffective rate for Real Power Losses and
a quantity of energy equal to four (4)
percent of the total non-Federal energy
transmitted by Southwestern on behalf
of each such customer during that
month.
Beginning January 1, 2009,
Southwestern is proposing to
implement revised real power loss
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provisions, as specified in
Southwestern’s proposed P–06A and
NFTS–06A rate schedules, which will
require that all real power losses
associated with deliveries of nonFederal energy transmitted by
Southwestern must be scheduled and
delivered (self-supplied) to
Southwestern by customers during the
second month after such real power
losses were incurred by Southwestern.
Southwestern will determine the
amount of real power losses associated
with non-Federal energy transmitted on
behalf of each customer in the same
manner specified in the previous P–06
and NFTS–06 rate schedules and
provide a written schedule setting forth
the delivery rate and total quantity of
real power loss energy to be delivered
back to Southwestern. Should a
customer fail to return the total quantity
of real power loss energy to
Southwestern, according to the schedule
provided during the month in which
such loss energy is due, the customer
will be invoiced and obligated to
purchase, at the rate stipulated in the P–
06A and NFTS–06A rate schedules, the
quantity of loss energy the customer
failed to return to Southwestern.
P–06 and NFTS–06 Rate Schedule
Revisions
In developing the revised real power
losses rate schedule provisions, the
titles of the P–06 and NFTS–06 rate
schedules were changed to P–06A and
NFTS–06A respectively to reflect the
fact that revisions have been made. In
addition to replacing the section
entitled ‘‘Rates for Real Power Losses’’
within each rate schedule, minor
corrections and modifications were
incorporated to clarify and update any
sections of the rate schedules containing
references to real power losses.
Redlined versions of rate schedules P–
06 and NFTS–06, which show revisions
proposed by rate schedules P–06A and
NFTS–06A, will be made available upon
request. To request a copy, please
contact Scott Carpenter
(scott.carpenter@swpa.gov) at 918–595–
6694 or Stephanie Bradley
(stephanie.bradley@swpa.gov) at 918–
595–6676. Southwestern will
implement the revised P–06A and
NFTS–06A rate schedule language and
provisions upon the Deputy Secretary’s
interim approval.
The Administrator has determined
that written comments will provide
adequate opportunity for public
participation in the rate schedule
revision process. Therefore, an
opportunity is presented for interested
parties to submit written comments on
the proposed rate schedule changes.
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Written comments are due on or before
November 28, 2008. Written comments
should be submitted to Mr. James K.
McDonald, Assistant Administrator,
Office of Corporate Operations,
Southwestern Power Administration,
U.S. Department of Energy, One West
Third Street, Tulsa, Oklahoma 74103,
(918) 595–6690,
jim.mcdonald@swpa.gov.
Following review and consideration
of written comments, the Administrator
will finalize and submit the proposed
rate schedules to the Deputy Secretary
of Energy for confirmation and approval
on an interim basis, and subsequently to
the FERC for confirmation and approval
on a final basis. The FERC will allow
the public an opportunity to provide
written comments on the proposed rate
schedule change before making a final
decision.
Dated: October 21, 2008.
Jon C. Worthington,
Administrator.
United States Department of Energy
Southwestern Power Administration
Rate Schedule NFTS–06A1 Wholesale Rates
for Non-Federal Transmission/
Interconnection Facilities Service
Effective
During the period January 1, 2009, through
September 30, 2010, in accordance with
Federal Energy Regulatory Commission order
issued llllll, Docket No.
llllll.
Available
In the region where Southwestern Power
Administration (Southwestern) owns and
operates high-voltage transmission lines and
related facilities, and/or has contractual
rights to such transmission facilities owned
by others (System of Southwestern).
Applicable
To Customers which have executed Service
Agreements with Southwestern for the
transmission of non-Federal power and
energy over the System of Southwestern or
for its use for interconnections. Southwestern
will provide services over those portions of
the System of Southwestern in which the
Administrator, Southwestern, in his or her
sole judgment, has determined that
uncommitted transmission and
transformation capacities in the System of
Southwestern are and will be available in
excess of the capacities required to market
Federal power and energy pursuant to
Section 5 of the Flood Control Act of 1944
(58 Stat. 887,890; 16 U.S.C. 825s).
Character and Conditions of Service
Service will be provided as 3-phase,
alternating current, at approximately 60
Hertz, and at the voltage level of the point(s)
specified by Service Agreement or
Transmission Service Transaction.
1 Supersedes
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Definitions of Terms
A Customer is the entity which is utilizing
and/or purchasing services from
Southwestern pursuant to this rate schedule.
A ‘‘Service Agreement’’ is a contract
executed between a Customer and
Southwestern for the transmission of nonFederal power and energy over the System of
Southwestern or for interconnections.
Service Agreements include:
‘‘Firm Transmission Service Agreements’’
that provide for reserved transmission
capacity on a firm basis, for a particular
point-to-point delivery path.
‘‘Non-Firm Transmission Service
Agreements’’ that provide for the Customer to
request transmission service on a non-firm
basis.
‘‘Network Transmission Service
Agreements’’ that provide for the Customer to
request firm transmission service for the
delivery of capacity and energy from the
Customer’s network resources to the
Customer’s network load, for a period of one
year or more.
‘‘Interconnection Agreements’’ that provide
for the use of the System of Southwestern
and recognize the exchange of mutual
benefits for such use or provide for
application of a charge for Interconnection
Facilities Service.
A ‘‘Service Request’’ is made under a
Transmission Service Agreement through the
Southwest Power Pool, Inc. (SPP) Open
Access Same-Time Information System
(OASIS) for reservation of transmission
capacity over a particular point-to-point
delivery path for a particular period. When
a Service Request is approved by SPP, it
becomes a ‘‘Transmission Service
Transaction.’’ The Customer must submit
hourly schedules for actual service in
addition to the Service Request.
‘‘Firm Point-to-Point Transmission
Service’’ is transmission service reserved on
a firm basis between specific points of receipt
and delivery pursuant to either a Firm
Transmission Agreement or to a
Transmission Service Transaction. ‘‘NonFirm Point-to-Point Transmission Service’’ is
transmission service reserved on a non-firm
basis for specific points of receipt and
delivery pursuant to a Transmission Service
Transaction. ‘‘Network Integration
Transmission Service’’ is transmission
service provided under Part III of
Southwestern’s Open Access Transmission
Service Tariff which provides the Customer
with firm transmission service for the
delivery of capacity and energy from the
Customer’s resources to the Customer’s load.
‘‘Secondary Transmission Service’’ is
associated with Firm Point-to-Point
Transmission Service and Network
Integration Transmission Service. For Firm
Point-to-Point Transmission Service, it
consists of transmission service provided on
an as-available, non-firm basis, scheduled
within the limits of a particular capacity
reservation for transmission service, and
scheduled from points of receipt, or to points
of delivery, other than those designated in a
Long-Term Firm Transmission Agreement or
a Transmission Service Transaction for Firm
Point-to-Point Transmission Service. For
Network Integration Transmission Service,
Secondary Transmission Service consists of
transmission service provided on an asavailable, non-firm basis, from resources
other than the Network Resources designated
in a Network Transmission Service
Agreement, to meet the Customer’s Network
Load. The charges for Secondary
Transmission Service, other than Ancillary
Services, are included in the applicable
capacity charges for Firm Point-to-Point
Transmission Service and Network
Integration Transmission Service.
The ‘‘Demand Period’’ used to determine a
maximum integrated rate of delivery for the
purposes of power accounting is the 60minute period which begins with the change
of hour. The term ‘‘Peak Demand’’ means the
highest rate of delivery, in kilowatts, for any
Demand Period during a particular month, at
any particular point of delivery or
interconnection.
For the purposes of this rate schedule, the
term ‘‘Point of Delivery’’ is used to mean
either a single physical point to which
electric power and energy are delivered from
the System of Southwestern, or a specified
set of delivery points which together form a
single, electrically integrated load. Peak
Demand for such set of points is computed
as the coincidental highest rate of delivery
among the specified points rather than as the
63971
sum of peak demands for each individual
physical point.
‘‘Ancillary Services’’ are those services
necessary to support the transmission of
capacity and energy from resources to loads
while maintaining reliable operation of the
System of Southwestern in accordance with
good utility practice. Ancillary Services
include:
‘‘Scheduling, System Control, and Dispatch
Service’’ is provided by Southwestern as
Control Area operator and is in regard to
interchange and load-match scheduling and
related system control and dispatch
functions.
‘‘Reactive Supply and Voltage Control from
Generation Sources Service’’ is provided at
transmission facilities in the System of
Southwestern to produce or absorb reactive
power and to maintain transmission voltages
within specific limits.
‘‘Regulation and Frequency Response
Service’’ is the continuous balancing of
generation and interchange resources
accomplished by raising or lowering the
output of on-line generation as necessary to
follow the moment-by-moment changes in
load and to maintain frequency within a
Control Area.
‘‘Spinning Operating Reserve Service’’
maintains generating units on-line, but
loaded at less than maximum output, which
may be used to service load immediately
when disturbance conditions are experienced
due to a sudden loss of generation or load.
‘‘Supplemental Operating Reserve Service’’
provides an additional amount of operating
reserve sufficient to reduce Area Control
Error to zero within 10 minutes following
loss of generating capacity which would
result from the most severe single
contingency.
‘‘Energy Imbalance Service’’ corrects for
differences over a period of time between
schedules and actual hourly deliveries of
energy to a load.
‘‘Interconnection Facilities Service’’
provides for the use of the System of
Southwestern to deliver energy and/or
provide system support at an
interconnection.
Rates for Firm Point-to-Point Transmission
Service
CAPACITY CHARGES FOR FIRM TRANSMISSION SERVICE
10/1/2006–9/30/2008
Monthly .......
Weekly ........
ebenthall on PROD1PC60 with NOTICES
Daily ............
10/1/2008–9/30/2010
$0.90 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a longer term agreement.
$0.225 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0409 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.95 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a longer term agreement.
$0.238 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0432 per kilowatt of transmission capacity reserved in increments of one day of service.
Service Associated With Capacity Charges
for Firm Point-to-Point Transmission Service
Application of Capacity Charges for Firm
Point-to-Point Transmission Service
The capacity charge for firm transmission
service includes Secondary Transmission
Service, but does not include charges for
Ancillary Services associated with actual
schedules.
Capacity charges for firm transmission
service are applied to quantities reserved by
contract under a Firm Transmission
Agreement or in accordance with a
Transmission Service Transaction.
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Customers, unless otherwise specified by
contract, will be charged on the greatest of (1)
the Peak Demand at any particular point of
delivery during a particular month, rounded
up to the nearest whole megawatt, or (2) the
highest Peak Demand recorded at such point
of delivery during any of the previous 11
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months, rounded up to the nearest whole
megawatt, or (3) the capacity reserved by
contract; which amount shall be considered
such Customer’s reserved capacity.
Secondary Transmission Service for such
Customers shall be limited during any month
to the most recent Peak Demand on which a
particular Customer is billed or to the
capacity reserved by contract, whichever is
greater.
Rates for Non-Firm Point-to-Point
Transmission Service
Capacity Charges for Non-Firm Transmission
Service
Monthly: 80 percent of the firm monthly
charge of transmission capacity reserved in
increments of one month of service.
Weekly: 80 percent of the firm monthly
charge divided by 4 of transmission capacity
reserved in increments of one week of
service.
Daily: 80 percent of the firm monthly
charge divided by 22 of transmission
capacity reserved in increments of one day of
service.
Hourly: 80 percent of the firm monthly
charge divided by 352 of transmission
capacity reserved in increments of one hour
of service.
Application of Charges for Non-Firm Pointto-Point Transmission Service
Capacity charges for Non-Firm
Transmission Service are applied to
quantities reserved under a Transmission
Service Transaction, and do not include
charges for Ancillary Services.
Rates for Network Integration Transmission
Service
10/1/2006–9/30/2008
10/1/2008–9/30/2010
Annual Revenue Requirement for Network Integration Service
$9,155,900 .....................................................................................................................................................
$9,431,500.
Monthly Revenue Requirement for Network Integration Service
$762,992 ........................................................................................................................................................
$785,958.
Net Capacity Available for Network Integration Service
845,000 kilowatts ...........................................................................................................................................
828,000 kilowatts.
Capacity Charge for Network Integration Transmission Service
$0.90 per kilowatt of Network Load ($762,992/845,000 kilowatts) ...............................................................
ebenthall on PROD1PC60 with NOTICES
Application of Charge for Network
Integration Transmission Service
Network Integration Transmission Service
is available only for deliveries of non-Federal
power and energy, and is applied to the
Customer utilizing such service exclusive of
any deliveries of Federal power and energy.
The capacity on which charges for any
particular Customer utilizing this service is
determined on the greatest of (1) the Peak
Demand at any particular point of delivery
during a particular month, rounded up to the
nearest whole megawatt, or (2) the highest
Peak Demand recorded at such point of
delivery during any of the previous 11
months, rounded up to the nearest whole
megawatt.
For those Customers taking Network
Integration Transmission Service who are
also taking delivery of Federal Power and
Energy, the Peak Demand shall be
determined by subtracting the energy
scheduled for delivery of Federal Power and
Energy for any hour from the metered
demand for such hour.
Secondary transmission Service for such
Customers shall be limited during any month
to the most recent Peak Demand on which a
particular Customer is billed. Charges for
Ancillary Services shall also be assessed.
Real Power Losses
Customers are required to self-provide all
Real Power Losses for non-Federal energy
transmitted by Southwestern on behalf of
such Customers under the provisions
detailed below.
Real Power Losses are computed as four (4)
percent of the total amount of non-Federal
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energy transmitted by Southwestern. The
Customer’s Monthly Real Power Losses are
computed each month on a megawatthour
basis as follows:
ML = .04 × NFE
with the factors defined as follows:
ML = The total monthly loss energy, rounded
to the nearest megawatthour, to be
scheduled by a Customer for receipt by
Southwestern for Real Power Losses
associated with non-Federal energy
transmitted on behalf of such Customer;
and
NFE = The amount of non-Federal energy
that was transmitted by Southwestern on
behalf of a Customer during a particular
month.
The Customer must schedule or cause to be
scheduled to Southwestern, Real Power
Losses for which it is responsible subject to
the following conditions:
(1) The Customer shall schedule and
deliver real power losses back to
Southwestern during the second month after
they were incurred by Southwestern in the
transmission of the Customer’s non-Federal
power and energy over the System of
Southwestern.
(2) On or before the twentieth day of each
month, Southwestern shall determine the
amount of non-Federal loss energy it
provided on behalf of the Customer during
the previous month and provide a written
schedule to the Customer setting forth hourby-hour the quantities of non-Federal energy
to be delivered to Southwestern as losses
during the next month.
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$0.95 per kilowatt of Network Load
($785,958/828,000 kilowatts).
(3) Real Power Losses not delivered to
Southwestern by the Customer, according to
the schedule provided, during the month in
which such losses are due shall be billed by
Southwestern to the Customer to adjust the
end-of-month loss energy balance to 0
megawatthours and the Customer shall be
obliged to purchase such energy at the
following rates:
Months associated with
charge
March, April, May, October,
November, December .......
January, February, June,
July, August, September ...
Rate per
kilowatthour
$0.15
0.30
(6) Real Power Losses delivered to
Southwestern by the Customer in excess of
the losses due during the month shall be
purchased by Southwestern from the
Customer at a rate per megawatthour equal to
Southwestern’s rate per megawatthour for
Supplemental Peaking Energy, as set forth in
Southwestern’s then-effective Rate Schedule
for hydro peaking power to adjust such
hourly end-of-month loss energy balance to
0 megawatthours.
Monthly Capacity Charges for
Transformation Service
A charge of $0.30 per kilowatt will be
assessed for capacity used to deliver energy
at any point of delivery at which
Southwestern provides transformation for
deliveries at voltages of 69 kilovolts or less
from higher voltage facilities.
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Application of Capacity Charges for
Transformation Service
For any particular month, charges for
transformation service will be assessed on
the greater of (1) that month’s actual Peak
Demand, or (2) the highest Peak Demand
recorded during the previous 11 months. For
the purpose of this rate schedule, the Peak
Demand will be based on all deliveries, of
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both Federal and non-Federal energy, from
the System of Southwestern, at such point
during such month.
Rates for Ancillary Services
CAPACITY CHARGES FOR ANCILLARY SERVICES ASSOCIATED WITH TRANSMISSION SERVICES
10/1/2006–9/30/2008
10/1/2008–9/30/2010
(a) Scheduling, System Control, and Dispatch Service
.
Monthly .......
Weekly ........
Daily ............
Hourly ..........
$0.06 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.015 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0027 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00017 per kilowatt of energy delivered as non-firm transmission service.
$0.06 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.015 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0027 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00017 per kilowatt of energy delivered as non-firm transmission service.
(b) Reactive Supply and Voltage Control From Generation Sources Service
Monthly .......
Weekly ........
Daily ............
Hourly ..........
$0.03 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.008 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0014 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00009 per kilowatt of energy delivered as non-firm transmission service.
$0.04 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.010 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0018 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00011 per kilowatt of energy delivered as non-firm transmission service.
(c) Regulation and Frequency Response Service
Monthly .......
Weekly ........
Daily ............
Hourly ..........
$0.08 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.020 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0036 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00023 per kilowatt of energy delivered as non-firm transmission service.
$0.09 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.023 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.0041 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00026 per kilowatt of energy delivered as non-firm transmission service.
(d) Spinning Operating Reserve Service
Monthly .......
Weekly ........
Daily ............
Hourly: .........
$0.0079 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.00198 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.00036 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00002 per kilowatt of energy delivered as non-firm transmission service.
$0.0092 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.0023 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.00042 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00003 per kilowatt of energy delivered as non-firm transmission service.
(e) Supplemental Operating Reserve Service
ebenthall on PROD1PC60 with NOTICES
Monthly .......
Weekly ........
Daily ............
Hourly ..........
VerDate Aug<31>2005
$0.0079 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.00198 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.00036 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00002 per kilowatt of energy delivered as non-firm transmission service.
15:28 Oct 27, 2008
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Frm 00032
Fmt 4703
$0.0092 per kilowatt of transmission capacity reserved in increments of one month of service or invoiced in accordance
with a Long-Term Firm Transmission Agreement or Network
Transmission Service Agreement.
$0.0023 per kilowatt of transmission capacity reserved in increments of one week of service.
$0.00042 per kilowatt of transmission capacity reserved in increments of one day of service.
$0.00003 per kilowatt of energy delivered as non-firm transmission service.
Sfmt 4703
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Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
(f) Energy Imbalance Service: $0.0 per
kilowatt for all periods of reservation.
Availability of Ancillary Services
Ancillary Services (a) and (b) are available
for all transmission services in and from the
System of Southwestern and shall be
provided by Southwestern. Ancillary
Services (c) and (f) listed above are available
only for deliveries of power and energy
serving load within Southwestern’s Control
Area and shall be provided by Southwestern,
unless, subject to Southwestern’s approval,
they are provided by others. Ancillary
Services (d) and (e) are available only for
deliveries of power and energy generated by
resources located within Southwestern’s
Control Area and shall be provided by
Southwestern, unless, subject to
Southwestern’s approval, they are provided
by others.
Application of Ancillary Services Charges
Charges for all Ancillary Services are
applied to the reserved or network
transmission service taken by the Customer
in accordance with the rates listed above
when such services are provided by
Southwestern.
The charges for Ancillary Services are
considered to include Ancillary Services for
any Secondary Transmission Service, except
in cases where Ancillary Services (c) through
(f) are applicable to a Secondary
Transmission Service transaction, but are not
applicable to the firm capacity reservation
under which Secondary Transmission
Service is provided. When charges for
Ancillary Services are applicable to
Secondary Transmission Service, the charge
for the Ancillary Service shall be the hourly
rate applied to all energy transmitted
utilizing the Secondary Transmission
Service.
ebenthall on PROD1PC60 with NOTICES
Provision of Ancillary Services by Others
Customers for which Ancillary Services (c)
through (f) are made available as specified
above must inform Southwestern by written
notice of the Ancillary Services which they
do not intend to take and purchase from
Southwestern, and their election to provide
all or part of such Ancillary Services from
their own resources or a third party.
Subject to Southwestern’s approval of the
ability of such resources or third parties to
meet Southwestern’s technical requirements
for provision of such Ancillary Services, the
customer may change the Ancillary Services
which it takes from Southwestern and/or
from other sources at the beginning of any
month upon the greater of 60 days written
notice or upon the completion of any
necessary equipment modifications necessary
to accommodate such change. Such notice
requirements also apply to requests for
Southwestern to provide Ancillary Services
when such services are available as specified
above.
Limitations on Energy Imbalance Service
Energy Imbalance Service is authorized for
use only within a bandwidth of ± 1.5 percent
of the actual requirements of the load at a
particular point of delivery, for any hour,
compared to the resources scheduled to meet
such load during such hour. Deviations
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15:28 Oct 27, 2008
Jkt 217001
which are greater than ± 1.5 percent, but
which are less than ± 2,000 kilowatts, are
considered to be within the authorized
bandwidth. Deviations outside the
authorized bandwidth are subject to a
Capacity Overrun Penalty.
Energy delivered or received within the
authorized bandwidth for this service is
accounted for as an inadvertent flow and will
be netted against flows in the future. The
inadvertent flow in any given hour will only
be offset with the flows in the corresponding
hour of a day in the same category. The two
categories of days are weekdays and weekend
days/North American Electric Reliability
Council holidays. This process will result in
a separate inadvertent accumulation for each
hour of the two categories of days. The
hourly accumulations in the current month
will be added to the hourly inadvertent
balances from the previous month, resulting
in a month-end balance for each hour.
The Customer is required to adjust the
scheduling of resources in such a way as to
reduce the accumulation towards zero. It is
recognized that the inadvertent hourly flows
can be both negative and positive, and that
offsetting flows should deter a significant
accumulation of inadvertent. In the event any
hourly month-end balance exceeds 12
MWHs, the excess will be subject to the
Application of Capacity Overrun Penalty or
the Unauthorized Use of Energy Imbalance
Service by Overscheduling of Resources
provisions, depending on the direction of the
accumulation.
Application of Capacity Overrun Penalty
Customers, who receive deliveries within
Southwestern’s Control Area, are obligated to
provide resources sufficient to meet their
loads. Such obligation is not related to the
amount of transmission capacity that such
Customers may have reserved for
transmission service to a particular load.
Customers whose resources are scheduled by
Southwestern are not subject to this
provision. In the event that a Customer under
schedules its resources to meet its load,
resulting in a difference between resources
and actual metered load (adjusted for
transformer losses as applicable) outside the
authorized bandwidth for Energy Imbalance
Service for any hour, then such Customer is
subject to the following penalty:
Capacity Overrun Penalty
For each hour during which energy flows
outside the authorized bandwidth, the
Customer will be obliged to purchase such
energy at the following rates:
Months associated with
charge
March, April, May, October,
November, December .......
January, February, June,
July, August, September ...
Rate per
kilowatt
$0.15
0.30
Unauthorized Use of Energy Imbalance
Service by Overscheduling of Resources
In the event that a Customer schedules
greater resources than are needed to meet its
load, such that energy flows at rates beyond
the authorized bandwidth for the use of
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Fmt 4703
Sfmt 4703
Energy Imbalance Service, Southwestern
retains such energy at no cost to
Southwestern and with no obligation to
return such energy. Customers whose
resources are scheduled by Southwestern are
not subject to this provision.
Application of Charge for Interconnection
Facilities Service
Any Customer that requests an
interconnection from Southwestern which, in
Southwestern’s sole judgment and at its sole
option, does not provide commensurate
benefits or compensation to Southwestern for
the use of its facilities shall be assessed a
capacity charge for Interconnection Facilities
Service. For any month, charges for
Interconnection Facilities Service shall be
assessed on the greater of (1) that month’s
actual Peak Demand, or (2) the highest Peak
Demand recorded during the previous eleven
months, as metered at the interconnection.
The use of Interconnection Facilities Service
will be subject to power factor provisions as
specified in this rate schedule. The
interconnection customer shall also schedule
and deliver Real Power Losses pursuant to
the provisions of this Rate Schedule based on
metered flow through the interconnection
where Interconnection Facilities Services is
assessed.
Rate for Interconnection Facilities Service
The monthly capacity charge for
Interconnection Facilities Service:
10/1/2006–9/30/2008
$0.90 per kilowatt .......
10/1/2008–9/30/2010
$0.95 per kilowatt.
Requirements Related to Power Factor
Any Customer served from facilities owned
by or available by contract to Southwestern
will be required to maintain a power factor
of not less than 95 percent and will be
subject to the following provisions.
Determination of Power Factor
The power factor will be determined for all
Demand Periods and shall be calculated
under the formula:
PF = kWh ÷
( kWh
2
)
+ rkVAh 2 ,
with the factors defined as follows:
PF = the power factor for any Demand Period
of the month.
kWh = the total quantity of energy which is
delivered during such Demand Period to
the point of delivery or interconnection.
rkVAh = the total quantity of reactive
kilovolt-ampere-hours (kvars) delivered
during such Demand Period to the point
of delivery or interconnection.
Power Factor Penalty and Assessment
The Customer shall be assessed a penalty
for all Demand Periods of a month where the
power factor is less than 95 percent lagging.
For any Demand Period during a particular
month such penalty shall be in accordance
with the following formula:
C = D × (.95¥LPF) × $0.10
with the factors defined as follows:
C = The charge in dollars to be assessed for
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63974
Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
any particular Demand Period of such
month that the Determination of Power
Factor ‘‘PF’’ is calculated to be less than
95 percent lagging.
D = The Customer’s demand in kilowatts at
the point of delivery for such Demand
Period in which a low power factor was
calculated.
LPF = The lagging power factor, if any,
determined by the formula ‘‘PF’’ for such
Demand Period.
If C is negative, then C = zero (0).
Applicable
To wholesale Customers which have
contractual rights from Southwestern to
purchase Hydro Peaking Power and
associated energy (Peaking Energy and
Supplemental Peaking Energy).
Application of Power Factor Penalty
The Power Factor Penalty is applicable to
radial interconnections with the System of
Southwestern. The total Power Factor
Penalty for any month shall be the sum of all
charges ‘‘C’’ for all Demand Periods of such
month. No penalty is assessed for leading
power factor. Southwestern, in its sole
judgment and at its sole option, may
determine whether power factor calculations
should be applied to a single physical point
of delivery or to multiple physical points of
delivery where a Customer has a single,
electrically integrated load served through
multiple points or interconnections. The
general criteria for such decision shall be
that, given the configuration of the
Customer’s and Southwestern’s systems,
Southwestern will determine, in its sole
judgment and at its sole option, whether the
power factor calculation more accurately
assesses the detrimental impact on
Southwestern’s system when the above
formula is calculated for a single physical
point of delivery or for a combination of
physical points or for an interconnection as
specified by an Interconnection Agreement.
Southwestern, at its sole option, may
reduce or waive power factor penalties when,
in Southwestern’s sole judgment, low power
factor conditions were not detrimental to the
System of Southwestern due to particular
loading and voltage conditions at the time
the power factor dropped below 95 percent
lagging.
Definitions of Terms
‘‘Customer’’ is the entity which is utilizing
and/or purchasing hydroelectric power and
associated energy and services from
Southwestern pursuant to this rate schedule.
The ‘‘Demand Period’’ used to determine
maximum integrated rates of delivery for the
purpose of power accounting is the 60minute period which begins with the change
of hour. The term ‘‘peak demand’’ means the
highest rate of delivery, in kilowatts, for any
Demand Period during a particular month, at
any particular point of delivery.
For the purposes of this Rate Schedule, the
term ‘‘point of delivery’’ is used to mean
either a single physical point at which
electric power and energy are delivered from
the System of Southwestern (defined below),
or a specified set of delivery points which
together form a single, electrically integrated
load. ‘‘Peak demand’’ for such set of delivery
points is computed as the coincidental
highest rate of delivery among the specified
points rather than as the sum of peak
demands for each individual physical point
of delivery.
The term ‘‘Peaking Contract Demand’’
means the maximum rate in kilowatts at
which Southwestern is, by contract, obligated
to deliver Peaking Energy during any
Demand Period. Unless otherwise provided
by contract, the ‘‘Peaking Billing Demand’’
for any month shall be equal to the ‘‘Peaking
Contract Demand.’’
The term ‘‘Uncontrollable Force,’’ as used
herein, shall mean any force which is not
within the control of the party affected,
including, but not limited to failure of water
supply, failure of facilities, flood, earthquake,
storm, lightning, fire, epidemic, war, riot,
civil disturbance, labor disturbance, sabotage,
or restraint by court of general jurisdiction,
which by exercise of due diligence and
foresight such party could not reasonably
have been expected to avoid.
The term ‘‘System of Southwestern’’ means
the high-voltage transmission lines and
related facilities Southwestern owns and
operates, and/or has contractual rights to
such transmission facilities owned by others.
‘‘Ancillary Services’’ are those services
necessary to support the transmission of
United States Department of Energy
Southwestern Power Administration
Rate Schedule P–06A 1 Wholesale Rates for
Hydro Peaking Power
Effective
During the period January 1, 2009, through
September 30, 2010, in accordance with Rate
Order No. SWPA–59 issued by the Deputy
Secretary of Energy on llll.
Available
In the marketing area of Southwestern
Power Administration (Southwestern),
described generally as the States of Arkansas,
Kansas, Louisiana, Missouri, Oklahoma, and
Texas.
Character and Conditions of Service
Three-phase, alternating current, delivered
at approximately 60 Hertz, at the nominal
voltage(s), at the points of delivery, and in
such quantities as are specified by contract.
63975
capacity and energy from resources to loads
while maintaining reliable operation of the
System of Southwestern in accordance with
good utility practice. Definitions of the
Ancillary Services are as follows:
‘‘Scheduling, System Control, and Dispatch
Service’’ is provided by Southwestern as
Control Area operator and is in regard to
interchange and load-match scheduling and
related system control and dispatch
functions.
‘‘Reactive Supply and Voltage Control from
Generation Sources Service’’ is provided at
transmission facilities in the System of
Southwestern to produce or absorb reactive
power and to maintain transmission voltages
within specific limits.
‘‘Regulation and Frequency Response
Service’’ is the continuous balancing of
generation and interchange resources
accomplished by raising or lowering the
output of on-line generation as necessary to
follow the moment-by-moment changes in
load and to maintain frequency within a
Control Area.
‘‘Spinning Operating Reserve Service’’
maintains generating units on-line, but
loaded at less than maximum output, which
may be used to service load immediately
when disturbance conditions are experienced
due to a sudden loss of generation or load.
‘‘Supplemental Operating Reserve Service’’
provides an additional amount of operating
reserve sufficient to reduce Area Control
Error to zero within 10 minutes following
loss of generating capacity which would
result from the most severe single
contingency.
‘‘Energy Imbalance Service’’ corrects for
differences over a period of time between
schedules and actual hourly deliveries of
energy to a load. Energy delivered or received
within the authorized bandwidth (defined
below) for this service is accounted for as an
inadvertent flow and is returned to the
providing party by the receiving party in
accordance with standard utility practice.
Energy Associated With Hydro Peaking
Power
Peaking Energy
1,200 kilowatthours of Peaking Energy per
kilowatt of Peaking Contract Demand will be
furnished during each contract year.
Supplemental Peaking Energy
Supplemental Peaking Energy (in addition
to Peaking Energy) will be furnished if and
when determined by Southwestern to be
available, and at rates of delivery which do
not exceed the Customer’s Peaking Contract
Demand.
Monthly Rates for Peaking Contract Demand
CAPACITY CHARGE FOR HYDRO PEAKING POWER
ebenthall on PROD1PC60 with NOTICES
10/1/2006–9/30/2007
10/1/2007–9/30/2008
10/1/2008–9/30/2010
$3.03 per kilowatt of Peaking Billing Demand .............
$3.18 per kilowatt of Peaking Billing Demand .............
$3.51 per kilowatt of Peaking
Billing Demand.
1 Supersedes
VerDate Aug<31>2005
Rate Schedule P–06.
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E:\FR\FM\28OCN1.SGM
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63976
Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
Services Associated With Capacity Charge
for Hydro Peaking Power
The capacity charge for Hydro Peaking
Power includes such transmission services as
are necessary to integrate Southwestern’s
resources in order to reliably deliver Hydro
Peaking Power and associated energy to
Customers. This capacity charge also
includes two ancillary services charges,
Scheduling, System Control and Dispatch
Service and Reactive Supply and Voltage
Control from Generation Sources Service.
Secondary Transmission Service Under
Capacity Associated With Hydro Peaking
Power
Customers may utilize the capacity
associated with Peaking Contract Demand for
the transmission of non-Federal energy, on a
non-firm, as-available basis, at no additional
charge for such transmission service or
associated Ancillary Services, under the
following terms and conditions:
(1) The sum of the capacity, for any hour,
which is used for Peaking Energy,
Supplemental Peaking Energy, and
Secondary Transmission Service, may not
exceed the Peaking Contract Demand;
10/1/2006–9/30/2007
(2) The non-Federal energy transmitted
under such secondary service is delivered to
the Customer’s point of delivery for Hydro
Peaking Power;
(3) The Customer commits to provide Real
Power Losses associated with such deliveries
of non-Federal energy; and
(4) Southwestern determines that sufficient
transfer capability exists between the point of
receipt into the System of Southwestern of
such non-Federal energy and the Customer’s
point of delivery for Hydro Peaking Power for
the time period that such secondary
transmission service is requested.
Rates for Energy Associated With Hydro
Peaking Power
10/1/2007–9/30/2008
10/1/2008–9/30/2010
(a) Peaking Energy Charge
$0.0082 per kilowatthour of Peaking Energy delivered;
plus (c).
$0.0082 per kilowatthour of Peaking Energy delivered;
plus (c).
$0.0082 per kilowatthour of
Peaking Energy delivered;
plus (c).
(b) Supplemental Energy Charge
$0.0055 per kilowatthour of Peaking Energy .................
(c) A purchased power adder of $0.0067
per kilowatthour of Peaking Energy
delivered, as adjusted by the Administrator,
Southwestern, in accordance with the
procedure within this rate schedule. This
adder does not apply to:
Supplemental Peaking Energy, or
Sales to any Customer which, by contract,
has assumed the obligation to supply
energy to fulfill the minimum of 1,200
kilowatthours of Peaking Energy per
kilowatt of Peaking Contract Demand
during a contract year (Contract Support
Arrangements).
$0.0082 per kilowatthour of Peaking Energy ................
Monthly Rates for Transformation Service
Capacity Charges for Transformation
Service: A charge of $0.30 per kilowatt will
be assessed for capacity used to deliver
energy at any point of delivery at which
Southwestern provides transformation
service for deliveries at voltages of 69
kilovolts or less from higher voltage facilities.
Application of Capacity Charges for
Transformation Service
For any particular month, charges for
transformation service will be assessed on
the greater of (1) that month’s actual peak
$0.0082 per kilowatthour of
Peaking Energy.
demand, or (2) the highest peak demand
recorded during the previous 11 months, at
any point of delivery. For the purpose of this
Rate Schedule, the peak demand will be
based on all deliveries, of both Federal and
non-Federal energy, from the System of
Southwestern, at such point during such
month.
Rates for Ancillary Services
Capacity Charges for Ancillary Services
10/1/2006–9/30/2008
10/1/2008–9/30/2010
(a) Regulation and Frequency Response Service
Monthly rate ................................................................
$0.08 per kilowatt of Peaking Billing Demand ...........
$0.09 per kilowatt of Peaking Billing Demand.
(b) Spinning Operating Reserve Service
Monthly rate ................................................................
$0.0079 per kilowatt of Peaking Billing Demand .......
Daily rate .....................................................................
$0.00036 per kilowatt for non-Federal generation inside Southwestern’s control area.
$0.0092 per kilowatt of Peaking
Billing Demand.
$0.00042 per kilowatt for non-Federal
generation
inside
Southwestern’s control area.
(c) Supplemental Operating Reserve Service
$0.0079 per kilowatt of Peaking Billing Demand .......
Daily rate .....................................................................
ebenthall on PROD1PC60 with NOTICES
Monthly rate ................................................................
$0.00036 per kilowatt for non-Federal generation inside Southwestern’s control area.
(d) Energy Imbalance Service: $0.0 per
kilowatt for all reservation periods.
VerDate Aug<31>2005
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Jkt 217001
Availability of Ancillary Services
Ancillary Services (a) and (d) listed above
are available only for deliveries of power and
energy to load centers within Southwestern’s
PO 00000
Frm 00035
Fmt 4703
Sfmt 4703
$0.0092 per kilowatt of Peaking
Billing Demand.
$0.00042 per kilowatt for non-Federal
generation
inside
Southwestern’s control area.
Control Area. Ancillary Services (b) and (c)
listed above are available only for deliveries
of non-Federal power and energy generated
by resources located within Southwestern’s
E:\FR\FM\28OCN1.SGM
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63977
Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
Capacity Overrun Penalty
For each hour during which Hydro Peaking
Power was provided at a rate greater than
that to which the Customer is entitled, the
Customer will be charged a capacity overrun
penalty at the following rates:
Months associated with
charge
Application of Ancillary Services Charges
For any month, the charges for Ancillary
Services (a), (b), (c) and (d) listed above for
deliveries of Hydro Peaking Power shall be
based on the Peaking Billing Demand.
The daily charge for Ancillary Services (b)
and (c) for non-Federal generation inside
Southwestern’s Control Area shall be applied
to the greater of Southwestern’s previous
day’s estimate of the peak, or the actual peak,
in kilowatts, of the internal non-Federal
generation.
Provision of Ancillary Services by Others
Customers for which Ancillary Services (a),
(b), (c) and (d) are made available as specified
above, must inform Southwestern by written
notice of the Ancillary Services which they
do not intend to take and purchase from
Southwestern, and of their election to
provide all or part of such Ancillary Services
from their own resources or from a third
party.
Subject to Southwestern’s approval of the
ability of such resources or third parties to
meet Southwestern’s technical requirements
for provision of such Ancillary Services, the
Customer may change the Ancillary Services
which it takes from Southwestern and/or
from other sources at the beginning of any
month upon the greater of 60 days notice or
upon completion of any necessary equipment
modifications necessary to accommodate
such change.
Limitations on Energy Imbalance Service
Energy Imbalance Service primarily
applies to deliveries of power and energy
which are required to satisfy a Customer’s
load. As Hydro Peaking Power and associated
energy are limited by contract, the Energy
Imbalance Service bandwidth specified in
Southwestern’s Open Access Transmission
Service tariff does not apply to deliveries of
Hydro Peaking Power, and therefore Energy
Imbalance Service is not charged on such
deliveries. Customers who consume a
capacity of Hydro Peaking Power greater than
their Peaking Contract Demand may be
subject to a Capacity Overrun Penalty.
ebenthall on PROD1PC60 with NOTICES
Application of Capacity Overrun Penalty
Customers which have loads within
Southwestern’s Control Area are obligated by
contract to provide resources, over and above
the Hydro Peaking Power and associated
energy purchased from Southwestern,
sufficient to meet their loads. A Capacity
Overrun Penalty shall be applied only when
the formulas provided in Customers’
contracts indicate an overrun on Hydro
Peaking Power, and investigation determines
that all resources, both firm and non-firm,
which were available at the time of the
apparent overrun were insufficient to meet
the Customer’s load.
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15:28 Oct 27, 2008
Jkt 217001
March, April, May, October,
November, December .......
January, February, June,
July, August, September ...
Rate per
kilowatt
$0.15
0.30
Application of Energy Overrun Penalty
By contract, the Customer is subject to
limitations on the maximum amounts of
Peaking Energy which may be scheduled
during any month or during any four
consecutive months. When the Customer
schedules an amount in excess of such
maximum amounts for any month, or
schedules more than 1,200 hours of Peaking
Energy per kilowatt of Peaking Contract
Demand in any contract year, such Customer
is subject to the Energy Overrun Penalty.
Energy Overrun Penalty
For each kilowatthour of overrun: $0.0902
per kilowatthour.
Real Power Losses
Customers are required to self-provide all
Real Power Losses for non-Federal energy
transmitted by Southwestern on behalf of
such Customers under the provisions
detailed below.
Real Power Losses are computed as four (4)
percent of the total amount of non-Federal
energy transmitted by Southwestern. The
Customer’s Monthly Real Power Losses are
computed each month on a megawatthour
basis as follows:
ML = .04 × NFE
with the factors defined as follows:
ML = The total monthly loss energy, rounded
to the nearest megawatthour, to be
scheduled by a Customer for receipt by
Southwestern for Real Power Losses
associated with non-Federal energy
transmitted on behalf of such Customer;
and
NFE = The amount of non-Federal energy
that was transmitted by Southwestern on
behalf of a Customer during a particular
month.
The Customer must schedule or cause to be
scheduled to Southwestern, Real Power
Losses for which it is responsible subject to
the following conditions:
(1) The Customer shall schedule and
deliver real power losses back to
Southwestern during the second month after
they were incurred by Southwestern in the
transmission of the Customer’s non-Federal
power and energy over the System of
Southwestern.
(2) On or before the twentieth day of each
month, Southwestern shall determine the
amount of non-Federal loss energy it
provided on behalf of the Customer during
the previous month and provide a written
schedule to the Customer setting forth hourby-hour the quantities of non-Federal energy
PO 00000
Frm 00036
Fmt 4703
Sfmt 4703
to be delivered to Southwestern as losses
during the next month.
(4) Real Power Losses not delivered to
Southwestern by the Customer, according to
the schedule provided, during the month in
which such losses are due shall be billed by
Southwestern to the Customer to adjust the
end-of-month loss energy balance to 0
megawatthours and the Customer shall be
obliged to purchase such energy at the
following rates:
Months associated with
charge
Rate per
kilowatthour
March, April, May, October,
November, December .......
January, February, June,
July, August, September ...
$0.15
0.30
(5) Real Power Losses delivered to
Southwestern by the Customer in excess of
the losses due during the month shall be
purchased by Southwestern from the
Customer at a rate per megawatthour equal to
Southwestern’s rate per megawatthour for
Supplemental Peaking Energy, as set forth in
Southwestern’s then-effective Rate Schedule
for hydro peaking power to adjust such
hourly end-of-month loss energy balance to
0 megawatthours.
Requirements Related to Power Factor
Any Customer served from facilities owned
by or available by contract to Southwestern
will be required to maintain a power factor
of not less than 95 percent and will be
subject to the following provisions.
Determination of Power Factor
The power factor will be determined for all
Demand Periods and shall be calculated
under the formula:
PF = (kWh ) ÷
( kWh
2
)
+ rkVAh 2 ,
with the factors defined as follows:
PF = the power factor for any Demand Period
of the month.
kWh = the total quantity of energy which is
delivered during such Demand Period to
the point of delivery or interconnection.
rkVAh = the total quantity of reactive
kilovolt-ampere-hours (kvars) delivered
during such Demand Period to the point
of delivery or interconnection.
Power Factor Penalty and Assessment
The Customer shall be assessed a penalty
for all Demand Periods of a month where the
power factor is less than 95 percent lagging.
For any Demand Period during a particular
month such penalty shall be in accordance
with the following formula:
C = D × (.95–LPF) × $0.10
with the factors defined as follows:
C = The charge in dollars to be assessed for
any particular Demand Period of such
month that the Determination of Power
Factor ‘‘PF’’ is calculated to be less than
95 percent lagging.
D = The Customer’s demand in kilowatts at
the point of delivery for such Demand
Period in which a low power factor was
calculated.
E:\FR\FM\28OCN1.SGM
28OCN1
EN28OC08.002</MATH>
Control Area and for deliveries of all Hydro
Peaking Power and associated energy from
and within Southwestern’s Control Area.
Where available, such Ancillary Services
must be taken from Southwestern; unless,
subject to Southwestern’s approval, they are
provided by others.
63978
Federal Register / Vol. 73, No. 209 / Tuesday, October 28, 2008 / Notices
LPF = The lagging power factor, if any,
determined by the formula ‘‘PF’’ for such
Demand Period.
If C is negative, then C = zero (0).
ebenthall on PROD1PC60 with NOTICES
Application of Power Factor Penalty
The Power Factor Penalty is applicable to
radial interconnections with the System of
Southwestern. The total Power Factor
Penalty for any month shall be the sum of all
charges ‘‘C’’ for all Demand Periods of such
month. No penalty is assessed for leading
power factor. Southwestern, in its sole
judgment and at its sole option, may
determine whether power factor calculations
should be applied to a single physical point
of delivery or to multiple physical points of
delivery where a Customer has a single,
electrically integrated load served through
multiple points or interconnections. The
general criteria for such decision shall be
that, given the configuration of the
Customer’s and Southwestern’s systems,
Southwestern will determine, in its sole
judgment and at its sole option, whether the
power factor calculation more accurately
assesses the detrimental impact on
Southwestern’s system when the above
formula is calculated for a single physical
point of delivery or for a combination of
physical points or for an interconnection as
specified by an Interconnection Agreement.
Southwestern, at its sole option, may
reduce or waive power factor penalties when,
in Southwestern’s sole judgment, low power
factor conditions were not detrimental to the
System of Southwestern due to particular
loading and voltage conditions at the time
the power factor dropped below 95 percent
lagging.
Adjustment for Reduction in Service
If, during any month, the quantity of
Peaking Contract Demand of Southwestern’s
1200 hour peaking power sales customers
that is scheduled by the customer for
delivery is reduced by Southwestern for a
period or periods of not less than two
consecutive hours by reason of an outage
caused by either an Uncontrollable Force or
by the installation, maintenance, replacement
or malfunction of generation, transmission
and/or related facilities on the System of
Southwestern, or insufficient pool levels, the
Customer’s capacity charges for such month
will be reduced for each such reduction in
service by an amount computed under the
formula:
R = (C × K × H) + S
with the factors defined as follows:
R = the dollar amount of reduction in the
monthly total capacity charges for a
particular reduction of not less than two
consecutive hours during any month,
except that the total amount of any such
reduction shall not exceed the product of
the Customer’s capacity charges
associated with Hydro Peaking Power
times the Peaking Billing Demand.
C = the Customer’s capacity charges
associated with Hydro Peaking Power for
the Peaking Billing Demand for such
month.
K = the reduction in kilowatts in Peaking
Billing Demand for a particular event.
VerDate Aug<31>2005
15:28 Oct 27, 2008
Jkt 217001
H = the number of hours duration of such
particular reduction.
S = the number of hours that Peaking Energy
is scheduled during such month, but not
less than 60 hours times the Peaking
Contract Demand.
Such reduction in charges shall fulfill
Southwestern’s obligation to deliver Peaking
Power and Peaking Energy.
Procedure for Determining Southwestern’s
Net Purchased Power Adder Adjustment
Not more than twice annually, the
Purchased Power Adder of $.0067 (6.7 mills)
per kilowatthour of Peaking Energy, as noted
in this Rate Schedule, may be adjusted by the
Administrator, Southwestern, by an amount
up to a total of ±$.0067 (6.7 mills) per
kilowatthour per year, as calculated by the
following formula:
ADJ = (PURCH¥EST + DIF) + SALES
with the factors defined as follows:
ADJ = the dollar amount of the total
adjustment, plus or minus, to be applied
to the Net Purchased Power Adder,
rounded to the nearest $.0001 per
kilowatthour, provided that the total ADJ
to be applied in any year shall not vary
from the then-effective ADJ by more than
$.0067 per kilowatthour;
PURCH = the actual total dollar cost of
Southwestern’s System Direct Purchases
as accounted for in the financial records
of the Southwestern Federal Power
System for the period;
EST = the estimated total dollar cost
($15,064,500 per year) of Southwestern’s
System Direct Purchases used as the
basis for the Purchased Power Adder of
$.0067 per kilowatthour of Peaking
Energy;
DIF = the accumulated remainder of the
difference in the actual and estimated
total dollar cost of Southwestern’s
System Direct Purchases since the
effective date of the currently approved
Purchased Power Adder set forth in this
rate schedule, which remainder is not
projected for recovery through the ADJ in
any previous periods;
SALES = the annual Total Peaking Energy
sales projected to be delivered
(2,241,300,000 KWh per year) from the
System of Southwestern, which total was
used as the basis for the $.0067 per
kilowatthour Purchased Power Adder.
[FR Doc. E8–25690 Filed 10–27–08; 8:45 am]
BILLING CODE 6450–01–P
PO 00000
Frm 00037
Fmt 4703
Sfmt 4703
ENVIRONMENTAL PROTECTION
AGENCY
[EPA–HQ–OEI–2008–0225; FRL–8735–1]
Agency Information Collection
Activities; Submission to OMB for
Review and Approval; Comment
Request; Tribal Capacity: Determining
the Capability To Participate in the
National Environmental Information
Exchange Network; EPA ICR No.
2299.01, OMB Control No. 2025—New
Environmental Protection
Agency (EPA).
ACTION: Notice.
AGENCY:
SUMMARY: In compliance with the
Paperwork Reduction Act (PRA) (44
U.S.C. 3501 et seq.), this document
announces that an Information
Collection Request (ICR) has been
forwarded to the Office of Management
and Budget (OMB) for review and
approval. This is a request for a new
collection. The ICR, which is abstracted
below, describes the nature of the
information collection and its estimated
burden and cost.
DATES: Additional comments may be
submitted on or before November 28,
2008.
ADDRESSES: Submit your comments,
referencing Docket ID No. EPA–HQ–
OEI–2008–0225, to (1) EPA online using
www.regulations.gov (our preferred
method), by e-mail to
alvarez.karl@epa.gov, by mail to: EPA
Docket Center, Environmental
Protection Agency, Tribal Capacity:
Determining the capability to participate
in the National Environmental
Information Exchange Network
Program, Environmental Protection
Agency, MC 2823T, 1200 Pennsylvania
Ave., NW., Washington, DC 20460, or by
hand delivery: EPA Docket Center, EPA
West Bldg., Room 3334, 1301
Constitution Ave., NW., Washington,
DC 20460. Such deliveries are only
accepted during the Docket’s normal
hours of operation, and special
arrangements should be made for
deliveries of boxed information; and (2)
OMB by mail to: Office of Information
and Regulatory Affairs, Office of
Management and Budget (OMB),
Attention: Desk Officer for EPA, 725
17th Street, NW., Washington, DC
20503.
FOR FURTHER INFORMATION CONTACT: Karl
Alvarez of OEI/OIC/IESD/IEPB at the
Environmental Protection Agency, 1200
Pennsylvania Ave., NW. (MC 2823–T),
Washington, DC 20460; telephone
number: (202) 566–0989; fax number:
(202) 566–1684; e-mail address:
alvarez.karl@epa.gov.
E:\FR\FM\28OCN1.SGM
28OCN1
]]>Agencies
[Federal Register Volume 73, Number 209 (Tuesday, October 28, 2008)]
[Notices]
[Pages 63969-63978]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E8-25690]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Southwestern Power Administration
Integrated System Rate Schedule Changes
AGENCY: Southwestern Power Administration, DOE.
ACTION: Notice of Proposed Changes to Southwestern Power Administration
Rate Schedules and Opportunity for Public Review and Comment.
-----------------------------------------------------------------------
SUMMARY: Due to the omission of the P-06A Rate Schedule from the Notice
of Proposed Changes to Southwestern Power Administration Rate Schedules
and Opportunity for Public Review and Comment published on October 20,
2008 (73 FR 62269), this notice is a resubmission to include both the
P-06A and the NFTS-06A Rate Schedule proposals for review and comment.
The Administrator, Southwestern Power Administration
(Southwestern), has determined that revisions to the Real Power Losses
provisions within existing rate schedules P-06 and NFTS-06 are
required. Since the proposed rate schedule revisions are limited only
to Real Power Losses, the net result of the 2006 Integrated System
Power Repayment Studies, which was the basis for the existing rate
schedules, will not be altered.
Southwestern held several meetings during FY 2008 with customers to
discuss the proposed rate schedule revisions and provide opportunity
for input in the development of the final rate schedules. As a result
of these informal meetings, it was determined that the revised rate
schedule provisions can provide cost-savings and operational benefits
to Southwestern's transmission customers and are consistent with
Federal Energy Regulatory Commission (FERC) Order No. 888.
DATES: The consultation and comment period will begin on the date of
publication of this Federal Register notice and will end November 28,
2008.
FOR FURTHER INFORMATION CONTACT: Mr. James K. McDonald, Assistant
Administrator, Office of Corporate Operations, Southwestern Power
Administration, U.S. Department of Energy, One West Third Street,
Tulsa, Oklahoma 74103, (918) 595-6690, jim.mcdonald@swpa.gov.
SUPPLEMENTARY INFORMATION: The U.S. Department of Energy (DOE) was
created by an Act of the U.S. Congress, Department of Energy
Organization Act, Public Law 95-91, dated August 4, 1977.
Southwestern's power marketing activities were transferred from the
[[Page 63970]]
Department of Interior to the DOE, effective October 1, 1977.
Guidelines for preparation of power repayment studies are included in
DOE Order No. RA 6120.2 entitled Power Marketing Administration
Financial Reporting. Procedures for Public Participation in Power and
Transmission Rate Adjustments of the Power Marketing Administrations
are found at Title 10, part 903, Subpart A of the Code of Federal
Regulations (10 CFR 903). Procedures for the confirmation and approval
of rates for the Federal Power Marketing Administrations are found at
Title 18, part 300, Subpart L of the Code of Federal Regulations (18
CFR 300).
Southwestern markets power from 24 multi-purpose reservoir
projects, with hydroelectric power facilities constructed and operated
by the U.S. Army Corps of Engineers. These projects are located in the
states of Arkansas, Missouri, Oklahoma, and Texas. Southwestern's
marketing area includes these states plus Kansas and Louisiana. The
costs associated with the hydropower facilities of 22 of the 24
projects are repaid via revenues received under the Integrated System
rates, as are Southwestern's transmission facilities that consist of
1,380 miles of high-voltage transmission lines, 24 substations, and 46
microwave and VHF radio sites. Costs associated with the Robert D.
Willis and Sam Rayburn Dams, two projects that are isolated
hydraulically, electrically, and financially from the Integrated System
are repaid by separate rate schedules.
Current and Proposed Real Power Losses Provisions
The current P-06 and NFTS-06 rate schedules determine the annual
rate for real power losses based upon the average of Southwestern's
actual costs for the purchase of energy to replace real power losses
during the previous Fiscal Year (October through September), as
reflected in Southwestern's financial records. Customers have the
option to either purchase losses from Southwestern or elect, on an
annual basis, to self-provide their respective loss energy subject to
certain conditions. Customers who purchase loss energy from
Southwestern are assessed a monthly charge equal to the product of
Southwestern's then-effective rate for Real Power Losses and a quantity
of energy equal to four (4) percent of the total non-Federal energy
transmitted by Southwestern on behalf of each such customer during that
month.
Beginning January 1, 2009, Southwestern is proposing to implement
revised real power loss provisions, as specified in Southwestern's
proposed P-06A and NFTS-06A rate schedules, which will require that all
real power losses associated with deliveries of non-Federal energy
transmitted by Southwestern must be scheduled and delivered (self-
supplied) to Southwestern by customers during the second month after
such real power losses were incurred by Southwestern. Southwestern will
determine the amount of real power losses associated with non-Federal
energy transmitted on behalf of each customer in the same manner
specified in the previous P-06 and NFTS-06 rate schedules and provide a
written schedule setting forth the delivery rate and total quantity of
real power loss energy to be delivered back to Southwestern. Should a
customer fail to return the total quantity of real power loss energy to
Southwestern, according to the schedule provided during the month in
which such loss energy is due, the customer will be invoiced and
obligated to purchase, at the rate stipulated in the P-06A and NFTS-06A
rate schedules, the quantity of loss energy the customer failed to
return to Southwestern.
P-06 and NFTS-06 Rate Schedule Revisions
In developing the revised real power losses rate schedule
provisions, the titles of the P-06 and NFTS-06 rate schedules were
changed to P-06A and NFTS-06A respectively to reflect the fact that
revisions have been made. In addition to replacing the section entitled
``Rates for Real Power Losses'' within each rate schedule, minor
corrections and modifications were incorporated to clarify and update
any sections of the rate schedules containing references to real power
losses. Redlined versions of rate schedules P-06 and NFTS-06, which
show revisions proposed by rate schedules P-06A and NFTS-06A, will be
made available upon request. To request a copy, please contact Scott
Carpenter (scott.carpenter@swpa.gov) at 918-595-6694 or Stephanie
Bradley (stephanie.bradley@swpa.gov) at 918-595-6676. Southwestern will
implement the revised P-06A and NFTS-06A rate schedule language and
provisions upon the Deputy Secretary's interim approval.
The Administrator has determined that written comments will provide
adequate opportunity for public participation in the rate schedule
revision process. Therefore, an opportunity is presented for interested
parties to submit written comments on the proposed rate schedule
changes. Written comments are due on or before November 28, 2008.
Written comments should be submitted to Mr. James K. McDonald,
Assistant Administrator, Office of Corporate Operations, Southwestern
Power Administration, U.S. Department of Energy, One West Third Street,
Tulsa, Oklahoma 74103, (918) 595-6690, jim.mcdonald@swpa.gov.
Following review and consideration of written comments, the
Administrator will finalize and submit the proposed rate schedules to
the Deputy Secretary of Energy for confirmation and approval on an
interim basis, and subsequently to the FERC for confirmation and
approval on a final basis. The FERC will allow the public an
opportunity to provide written comments on the proposed rate schedule
change before making a final decision.
Dated: October 21, 2008.
Jon C. Worthington,
Administrator.
United States Department of Energy Southwestern Power Administration
Rate Schedule NFTS-06A\1\ Wholesale Rates for Non-Federal Transmission/
Interconnection Facilities Service
---------------------------------------------------------------------------
\1\ Supersedes Rate Schedule NFTS-06.
---------------------------------------------------------------------------
Effective
During the period January 1, 2009, through September 30, 2010,
in accordance with Federal Energy Regulatory Commission order issued
------------, Docket No. ------------.
Available
In the region where Southwestern Power Administration
(Southwestern) owns and operates high-voltage transmission lines and
related facilities, and/or has contractual rights to such
transmission facilities owned by others (System of Southwestern).
Applicable
To Customers which have executed Service Agreements with
Southwestern for the transmission of non-Federal power and energy
over the System of Southwestern or for its use for interconnections.
Southwestern will provide services over those portions of the System
of Southwestern in which the Administrator, Southwestern, in his or
her sole judgment, has determined that uncommitted transmission and
transformation capacities in the System of Southwestern are and will
be available in excess of the capacities required to market Federal
power and energy pursuant to Section 5 of the Flood Control Act of
1944 (58 Stat. 887,890; 16 U.S.C. 825s).
Character and Conditions of Service
Service will be provided as 3-phase, alternating current, at
approximately 60 Hertz, and at the voltage level of the point(s)
specified by Service Agreement or Transmission Service Transaction.
[[Page 63971]]
Definitions of Terms
A Customer is the entity which is utilizing and/or purchasing
services from Southwestern pursuant to this rate schedule.
A ``Service Agreement'' is a contract executed between a
Customer and Southwestern for the transmission of non-Federal power
and energy over the System of Southwestern or for interconnections.
Service Agreements include:
``Firm Transmission Service Agreements'' that provide for
reserved transmission capacity on a firm basis, for a particular
point-to-point delivery path.
``Non-Firm Transmission Service Agreements'' that provide for
the Customer to request transmission service on a non-firm basis.
``Network Transmission Service Agreements'' that provide for the
Customer to request firm transmission service for the delivery of
capacity and energy from the Customer's network resources to the
Customer's network load, for a period of one year or more.
``Interconnection Agreements'' that provide for the use of the
System of Southwestern and recognize the exchange of mutual benefits
for such use or provide for application of a charge for
Interconnection Facilities Service.
A ``Service Request'' is made under a Transmission Service
Agreement through the Southwest Power Pool, Inc. (SPP) Open Access
Same-Time Information System (OASIS) for reservation of transmission
capacity over a particular point-to-point delivery path for a
particular period. When a Service Request is approved by SPP, it
becomes a ``Transmission Service Transaction.'' The Customer must
submit hourly schedules for actual service in addition to the
Service Request.
``Firm Point-to-Point Transmission Service'' is transmission
service reserved on a firm basis between specific points of receipt
and delivery pursuant to either a Firm Transmission Agreement or to
a Transmission Service Transaction. ``Non-Firm Point-to-Point
Transmission Service'' is transmission service reserved on a non-
firm basis for specific points of receipt and delivery pursuant to a
Transmission Service Transaction. ``Network Integration Transmission
Service'' is transmission service provided under Part III of
Southwestern's Open Access Transmission Service Tariff which
provides the Customer with firm transmission service for the
delivery of capacity and energy from the Customer's resources to the
Customer's load.
``Secondary Transmission Service'' is associated with Firm
Point-to-Point Transmission Service and Network Integration
Transmission Service. For Firm Point-to-Point Transmission Service,
it consists of transmission service provided on an as-available,
non-firm basis, scheduled within the limits of a particular capacity
reservation for transmission service, and scheduled from points of
receipt, or to points of delivery, other than those designated in a
Long-Term Firm Transmission Agreement or a Transmission Service
Transaction for Firm Point-to-Point Transmission Service. For
Network Integration Transmission Service, Secondary Transmission
Service consists of transmission service provided on an as-
available, non-firm basis, from resources other than the Network
Resources designated in a Network Transmission Service Agreement, to
meet the Customer's Network Load. The charges for Secondary
Transmission Service, other than Ancillary Services, are included in
the applicable capacity charges for Firm Point-to-Point Transmission
Service and Network Integration Transmission Service.
The ``Demand Period'' used to determine a maximum integrated
rate of delivery for the purposes of power accounting is the 60-
minute period which begins with the change of hour. The term ``Peak
Demand'' means the highest rate of delivery, in kilowatts, for any
Demand Period during a particular month, at any particular point of
delivery or interconnection.
For the purposes of this rate schedule, the term ``Point of
Delivery'' is used to mean either a single physical point to which
electric power and energy are delivered from the System of
Southwestern, or a specified set of delivery points which together
form a single, electrically integrated load. Peak Demand for such
set of points is computed as the coincidental highest rate of
delivery among the specified points rather than as the sum of peak
demands for each individual physical point.
``Ancillary Services'' are those services necessary to support
the transmission of capacity and energy from resources to loads
while maintaining reliable operation of the System of Southwestern
in accordance with good utility practice. Ancillary Services
include:
``Scheduling, System Control, and Dispatch Service'' is provided
by Southwestern as Control Area operator and is in regard to
interchange and load-match scheduling and related system control and
dispatch functions.
``Reactive Supply and Voltage Control from Generation Sources
Service'' is provided at transmission facilities in the System of
Southwestern to produce or absorb reactive power and to maintain
transmission voltages within specific limits.
``Regulation and Frequency Response Service'' is the continuous
balancing of generation and interchange resources accomplished by
raising or lowering the output of on-line generation as necessary to
follow the moment-by-moment changes in load and to maintain
frequency within a Control Area.
``Spinning Operating Reserve Service'' maintains generating
units on-line, but loaded at less than maximum output, which may be
used to service load immediately when disturbance conditions are
experienced due to a sudden loss of generation or load.
``Supplemental Operating Reserve Service'' provides an
additional amount of operating reserve sufficient to reduce Area
Control Error to zero within 10 minutes following loss of generating
capacity which would result from the most severe single contingency.
``Energy Imbalance Service'' corrects for differences over a
period of time between schedules and actual hourly deliveries of
energy to a load.
``Interconnection Facilities Service'' provides for the use of
the System of Southwestern to deliver energy and/or provide system
support at an interconnection.
Rates for Firm Point-to-Point Transmission Service
Capacity Charges for Firm Transmission Service
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.90 per kilowatt of transmission $0.95 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a longer term accordance with a longer term
agreement. agreement.
Weekly............................. $0.225 per kilowatt of transmission $0.238 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.0409 per kilowatt of transmission $0.0432 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one day of service. one day of service.
----------------------------------------------------------------------------------------------------------------
Service Associated With Capacity Charges for Firm Point-to-Point
Transmission Service
The capacity charge for firm transmission service includes
Secondary Transmission Service, but does not include charges for
Ancillary Services associated with actual schedules.
Application of Capacity Charges for Firm Point-to-Point Transmission
Service
Capacity charges for firm transmission service are applied to
quantities reserved by contract under a Firm Transmission Agreement
or in accordance with a Transmission Service Transaction.
Customers, unless otherwise specified by contract, will be
charged on the greatest of (1) the Peak Demand at any particular
point of delivery during a particular month, rounded up to the
nearest whole megawatt, or (2) the highest Peak Demand recorded at
such point of delivery during any of the previous 11
[[Page 63972]]
months, rounded up to the nearest whole megawatt, or (3) the
capacity reserved by contract; which amount shall be considered such
Customer's reserved capacity. Secondary Transmission Service for
such Customers shall be limited during any month to the most recent
Peak Demand on which a particular Customer is billed or to the
capacity reserved by contract, whichever is greater.
Rates for Non-Firm Point-to-Point Transmission Service
Capacity Charges for Non-Firm Transmission Service
Monthly: 80 percent of the firm monthly charge of transmission
capacity reserved in increments of one month of service.
Weekly: 80 percent of the firm monthly charge divided by 4 of
transmission capacity reserved in increments of one week of service.
Daily: 80 percent of the firm monthly charge divided by 22 of
transmission capacity reserved in increments of one day of service.
Hourly: 80 percent of the firm monthly charge divided by 352 of
transmission capacity reserved in increments of one hour of service.
Application of Charges for Non-Firm Point-to-Point Transmission Service
Capacity charges for Non-Firm Transmission Service are applied
to quantities reserved under a Transmission Service Transaction, and
do not include charges for Ancillary Services.
Rates for Network Integration Transmission Service
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
Annual Revenue Requirement for Network Integration Service
----------------------------------------------------------------------------------------------------------------
$9,155,900..................................... $9,431,500.
----------------------------------------------------------------------------------------------------------------
Monthly Revenue Requirement for Network Integration Service
----------------------------------------------------------------------------------------------------------------
$762,992....................................... $785,958.
----------------------------------------------------------------------------------------------------------------
Net Capacity Available for Network Integration Service
----------------------------------------------------------------------------------------------------------------
845,000 kilowatts.............................. 828,000 kilowatts.
----------------------------------------------------------------------------------------------------------------
Capacity Charge for Network Integration Transmission Service
----------------------------------------------------------------------------------------------------------------
$0.90 per kilowatt of Network Load ($762,992/ $0.95 per kilowatt of Network Load ($785,958/828,000
845,000 kilowatts). kilowatts).
----------------------------------------------------------------------------------------------------------------
Application of Charge for Network Integration Transmission Service
Network Integration Transmission Service is available only for
deliveries of non-Federal power and energy, and is applied to the
Customer utilizing such service exclusive of any deliveries of
Federal power and energy. The capacity on which charges for any
particular Customer utilizing this service is determined on the
greatest of (1) the Peak Demand at any particular point of delivery
during a particular month, rounded up to the nearest whole megawatt,
or (2) the highest Peak Demand recorded at such point of delivery
during any of the previous 11 months, rounded up to the nearest
whole megawatt.
For those Customers taking Network Integration Transmission
Service who are also taking delivery of Federal Power and Energy,
the Peak Demand shall be determined by subtracting the energy
scheduled for delivery of Federal Power and Energy for any hour from
the metered demand for such hour.
Secondary transmission Service for such Customers shall be
limited during any month to the most recent Peak Demand on which a
particular Customer is billed. Charges for Ancillary Services shall
also be assessed.
Real Power Losses
Customers are required to self-provide all Real Power Losses for
non-Federal energy transmitted by Southwestern on behalf of such
Customers under the provisions detailed below.
Real Power Losses are computed as four (4) percent of the total
amount of non-Federal energy transmitted by Southwestern. The
Customer's Monthly Real Power Losses are computed each month on a
megawatthour basis as follows:
ML = .04 x NFE
with the factors defined as follows:
ML = The total monthly loss energy, rounded to the nearest
megawatthour, to be scheduled by a Customer for receipt by
Southwestern for Real Power Losses associated with non-Federal
energy transmitted on behalf of such Customer; and
NFE = The amount of non-Federal energy that was transmitted by
Southwestern on behalf of a Customer during a particular month.
The Customer must schedule or cause to be scheduled to
Southwestern, Real Power Losses for which it is responsible subject
to the following conditions:
(1) The Customer shall schedule and deliver real power losses
back to Southwestern during the second month after they were
incurred by Southwestern in the transmission of the Customer's non-
Federal power and energy over the System of Southwestern.
(2) On or before the twentieth day of each month, Southwestern
shall determine the amount of non-Federal loss energy it provided on
behalf of the Customer during the previous month and provide a
written schedule to the Customer setting forth hour-by-hour the
quantities of non-Federal energy to be delivered to Southwestern as
losses during the next month.
(3) Real Power Losses not delivered to Southwestern by the
Customer, according to the schedule provided, during the month in
which such losses are due shall be billed by Southwestern to the
Customer to adjust the end-of-month loss energy balance to 0
megawatthours and the Customer shall be obliged to purchase such
energy at the following rates:
------------------------------------------------------------------------
Rate per
Months associated with charge kilowatthour
------------------------------------------------------------------------
March, April, May, October, November, December.......... $0.15
January, February, June, July, August, September........ 0.30
------------------------------------------------------------------------
(6) Real Power Losses delivered to Southwestern by the Customer
in excess of the losses due during the month shall be purchased by
Southwestern from the Customer at a rate per megawatthour equal to
Southwestern's rate per megawatthour for Supplemental Peaking
Energy, as set forth in Southwestern's then-effective Rate Schedule
for hydro peaking power to adjust such hourly end-of-month loss
energy balance to 0 megawatthours.
Monthly Capacity Charges for Transformation Service
A charge of $0.30 per kilowatt will be assessed for capacity
used to deliver energy at any point of delivery at which
Southwestern provides transformation for deliveries at voltages of
69 kilovolts or less from higher voltage facilities.
[[Page 63973]]
Application of Capacity Charges for Transformation Service
For any particular month, charges for transformation service
will be assessed on the greater of (1) that month's actual Peak
Demand, or (2) the highest Peak Demand recorded during the previous
11 months. For the purpose of this rate schedule, the Peak Demand
will be based on all deliveries, of both Federal and non-Federal
energy, from the System of Southwestern, at such point during such
month.
Rates for Ancillary Services
Capacity Charges for Ancillary Services Associated With Transmission Services
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
(a) Scheduling, System Control, and Dispatch Service
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.06 per kilowatt of transmission $0.06 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a Long-Term Firm accordance with a Long-Term Firm
Transmission Agreement or Network Transmission Agreement or Network
Transmission Service Agreement. Transmission Service Agreement.
Weekly............................. $0.015 per kilowatt of transmission $0.015 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.0027 per kilowatt of transmission $0.0027 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one day of service. one day of service.
Hourly............................. $0.00017 per kilowatt of energy $0.00017 per kilowatt of energy
delivered as non-firm transmission delivered as non-firm transmission
service. service.
----------------------------------------------------------------------------------------------------------------
(b) Reactive Supply and Voltage Control From Generation Sources Service
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.03 per kilowatt of transmission $0.04 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a Long-Term Firm accordance with a Long-Term Firm
Transmission Agreement or Network Transmission Agreement or Network
Transmission Service Agreement. Transmission Service Agreement.
Weekly............................. $0.008 per kilowatt of transmission $0.010 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.0014 per kilowatt of transmission $0.0018 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one day of service. one day of service.
Hourly............................. $0.00009 per kilowatt of energy $0.00011 per kilowatt of energy
delivered as non-firm transmission delivered as non-firm transmission
service. service.
----------------------------------------------------------------------------------------------------------------
(c) Regulation and Frequency Response Service
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.08 per kilowatt of transmission $0.09 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a Long-Term Firm accordance with a Long-Term Firm
Transmission Agreement or Network Transmission Agreement or Network
Transmission Service Agreement. Transmission Service Agreement.
Weekly............................. $0.020 per kilowatt of transmission $0.023 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.0036 per kilowatt of transmission $0.0041 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one day of service. one day of service.
Hourly............................. $0.00023 per kilowatt of energy $0.00026 per kilowatt of energy
delivered as non-firm transmission delivered as non-firm transmission
service. service.
----------------------------------------------------------------------------------------------------------------
(d) Spinning Operating Reserve Service
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.0079 per kilowatt of transmission $0.0092 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a Long-Term Firm accordance with a Long-Term Firm
Transmission Agreement or Network Transmission Agreement or Network
Transmission Service Agreement. Transmission Service Agreement.
Weekly............................. $0.00198 per kilowatt of transmission $0.0023 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.00036 per kilowatt of transmission $0.00042 per kilowatt of
capacity reserved in increments of transmission capacity reserved in
one day of service. increments of one day of service.
Hourly:............................ $0.00002 per kilowatt of energy $0.00003 per kilowatt of energy
delivered as non-firm transmission delivered as non-firm transmission
service. service.
----------------------------------------------------------------------------------------------------------------
(e) Supplemental Operating Reserve Service
----------------------------------------------------------------------------------------------------------------
Monthly............................ $0.0079 per kilowatt of transmission $0.0092 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one month of service or invoiced in one month of service or invoiced in
accordance with a Long-Term Firm accordance with a Long-Term Firm
Transmission Agreement or Network Transmission Agreement or Network
Transmission Service Agreement. Transmission Service Agreement.
Weekly............................. $0.00198 per kilowatt of transmission $0.0023 per kilowatt of transmission
capacity reserved in increments of capacity reserved in increments of
one week of service. one week of service.
Daily.............................. $0.00036 per kilowatt of transmission $0.00042 per kilowatt of
capacity reserved in increments of transmission capacity reserved in
one day of service. increments of one day of service.
Hourly............................. $0.00002 per kilowatt of energy $0.00003 per kilowatt of energy
delivered as non-firm transmission delivered as non-firm transmission
service. service.
----------------------------------------------------------------------------------------------------------------
[[Page 63974]]
(f) Energy Imbalance Service: $0.0 per kilowatt for all periods
of reservation.
Availability of Ancillary Services
Ancillary Services (a) and (b) are available for all
transmission services in and from the System of Southwestern and
shall be provided by Southwestern. Ancillary Services (c) and (f)
listed above are available only for deliveries of power and energy
serving load within Southwestern's Control Area and shall be
provided by Southwestern, unless, subject to Southwestern's
approval, they are provided by others. Ancillary Services (d) and
(e) are available only for deliveries of power and energy generated
by resources located within Southwestern's Control Area and shall be
provided by Southwestern, unless, subject to Southwestern's
approval, they are provided by others.
Application of Ancillary Services Charges
Charges for all Ancillary Services are applied to the reserved
or network transmission service taken by the Customer in accordance
with the rates listed above when such services are provided by
Southwestern.
The charges for Ancillary Services are considered to include
Ancillary Services for any Secondary Transmission Service, except in
cases where Ancillary Services (c) through (f) are applicable to a
Secondary Transmission Service transaction, but are not applicable
to the firm capacity reservation under which Secondary Transmission
Service is provided. When charges for Ancillary Services are
applicable to Secondary Transmission Service, the charge for the
Ancillary Service shall be the hourly rate applied to all energy
transmitted utilizing the Secondary Transmission Service.
Provision of Ancillary Services by Others
Customers for which Ancillary Services (c) through (f) are made
available as specified above must inform Southwestern by written
notice of the Ancillary Services which they do not intend to take
and purchase from Southwestern, and their election to provide all or
part of such Ancillary Services from their own resources or a third
party.
Subject to Southwestern's approval of the ability of such
resources or third parties to meet Southwestern's technical
requirements for provision of such Ancillary Services, the customer
may change the Ancillary Services which it takes from Southwestern
and/or from other sources at the beginning of any month upon the
greater of 60 days written notice or upon the completion of any
necessary equipment modifications necessary to accommodate such
change. Such notice requirements also apply to requests for
Southwestern to provide Ancillary Services when such services are
available as specified above.
Limitations on Energy Imbalance Service
Energy Imbalance Service is authorized for use only within a
bandwidth of 1.5 percent of the actual requirements of
the load at a particular point of delivery, for any hour, compared
to the resources scheduled to meet such load during such hour.
Deviations which are greater than 1.5 percent, but
which are less than 2,000 kilowatts, are considered to
be within the authorized bandwidth. Deviations outside the
authorized bandwidth are subject to a Capacity Overrun Penalty.
Energy delivered or received within the authorized bandwidth for
this service is accounted for as an inadvertent flow and will be
netted against flows in the future. The inadvertent flow in any
given hour will only be offset with the flows in the corresponding
hour of a day in the same category. The two categories of days are
weekdays and weekend days/North American Electric Reliability
Council holidays. This process will result in a separate inadvertent
accumulation for each hour of the two categories of days. The hourly
accumulations in the current month will be added to the hourly
inadvertent balances from the previous month, resulting in a month-
end balance for each hour.
The Customer is required to adjust the scheduling of resources
in such a way as to reduce the accumulation towards zero. It is
recognized that the inadvertent hourly flows can be both negative
and positive, and that offsetting flows should deter a significant
accumulation of inadvertent. In the event any hourly month-end
balance exceeds 12 MWHs, the excess will be subject to the
Application of Capacity Overrun Penalty or the Unauthorized Use of
Energy Imbalance Service by Overscheduling of Resources provisions,
depending on the direction of the accumulation.
Application of Capacity Overrun Penalty
Customers, who receive deliveries within Southwestern's Control
Area, are obligated to provide resources sufficient to meet their
loads. Such obligation is not related to the amount of transmission
capacity that such Customers may have reserved for transmission
service to a particular load. Customers whose resources are
scheduled by Southwestern are not subject to this provision. In the
event that a Customer under schedules its resources to meet its
load, resulting in a difference between resources and actual metered
load (adjusted for transformer losses as applicable) outside the
authorized bandwidth for Energy Imbalance Service for any hour, then
such Customer is subject to the following penalty:
Capacity Overrun Penalty
For each hour during which energy flows outside the authorized
bandwidth, the Customer will be obliged to purchase such energy at
the following rates:
------------------------------------------------------------------------
Rate per
Months associated with charge kilowatt
------------------------------------------------------------------------
March, April, May, October, November, December.......... $0.15
January, February, June, July, August, September........ 0.30
------------------------------------------------------------------------
Unauthorized Use of Energy Imbalance Service by Overscheduling of
Resources
In the event that a Customer schedules greater resources than
are needed to meet its load, such that energy flows at rates beyond
the authorized bandwidth for the use of Energy Imbalance Service,
Southwestern retains such energy at no cost to Southwestern and with
no obligation to return such energy. Customers whose resources are
scheduled by Southwestern are not subject to this provision.
Application of Charge for Interconnection Facilities Service
Any Customer that requests an interconnection from Southwestern
which, in Southwestern's sole judgment and at its sole option, does
not provide commensurate benefits or compensation to Southwestern
for the use of its facilities shall be assessed a capacity charge
for Interconnection Facilities Service. For any month, charges for
Interconnection Facilities Service shall be assessed on the greater
of (1) that month's actual Peak Demand, or (2) the highest Peak
Demand recorded during the previous eleven months, as metered at the
interconnection. The use of Interconnection Facilities Service will
be subject to power factor provisions as specified in this rate
schedule. The interconnection customer shall also schedule and
deliver Real Power Losses pursuant to the provisions of this Rate
Schedule based on metered flow through the interconnection where
Interconnection Facilities Services is assessed.
Rate for Interconnection Facilities Service
The monthly capacity charge for Interconnection Facilities
Service:
------------------------------------------------------------------------
10/1/2006-9/30/2008 10/1/2008-9/30/2010
------------------------------------------------------------------------
$0.90 per kilowatt................... $0.95 per kilowatt.
------------------------------------------------------------------------
Requirements Related to Power Factor
Any Customer served from facilities owned by or available by
contract to Southwestern will be required to maintain a power factor
of not less than 95 percent and will be subject to the following
provisions.
Determination of Power Factor
The power factor will be determined for all Demand Periods and
shall be calculated under the formula:
[GRAPHIC] [TIFF OMITTED] TN28OC08.001
with the factors defined as follows:
PF = the power factor for any Demand Period of the month.
kWh = the total quantity of energy which is delivered during such
Demand Period to the point of delivery or interconnection.
rkVAh = the total quantity of reactive kilovolt-ampere-hours (kvars)
delivered during such Demand Period to the point of delivery or
interconnection.
Power Factor Penalty and Assessment
The Customer shall be assessed a penalty for all Demand Periods
of a month where the power factor is less than 95 percent lagging.
For any Demand Period during a particular month such penalty shall
be in accordance with the following formula:
C = D x (.95-LPF) x $0.10
with the factors defined as follows:
C = The charge in dollars to be assessed for
[[Page 63975]]
any particular Demand Period of such month that the Determination of
Power Factor ``PF'' is calculated to be less than 95 percent
lagging.
D = The Customer's demand in kilowatts at the point of delivery for
such Demand Period in which a low power factor was calculated.
LPF = The lagging power factor, if any, determined by the formula
``PF'' for such Demand Period.
If C is negative, then C = zero (0).
Application of Power Factor Penalty
The Power Factor Penalty is applicable to radial
interconnections with the System of Southwestern. The total Power
Factor Penalty for any month shall be the sum of all charges ``C''
for all Demand Periods of such month. No penalty is assessed for
leading power factor. Southwestern, in its sole judgment and at its
sole option, may determine whether power factor calculations should
be applied to a single physical point of delivery or to multiple
physical points of delivery where a Customer has a single,
electrically integrated load served through multiple points or
interconnections. The general criteria for such decision shall be
that, given the configuration of the Customer's and Southwestern's
systems, Southwestern will determine, in its sole judgment and at
its sole option, whether the power factor calculation more
accurately assesses the detrimental impact on Southwestern's system
when the above formula is calculated for a single physical point of
delivery or for a combination of physical points or for an
interconnection as specified by an Interconnection Agreement.
Southwestern, at its sole option, may reduce or waive power
factor penalties when, in Southwestern's sole judgment, low power
factor conditions were not detrimental to the System of Southwestern
due to particular loading and voltage conditions at the time the
power factor dropped below 95 percent lagging.
United States Department of Energy Southwestern Power Administration
Rate Schedule P-06A \1\ Wholesale Rates for Hydro Peaking Power
---------------------------------------------------------------------------
\1\ Supersedes Rate Schedule P-06.
---------------------------------------------------------------------------
Effective
During the period January 1, 2009, through September 30, 2010,
in accordance with Rate Order No. SWPA-59 issued by the Deputy
Secretary of Energy on --------.
Available
In the marketing area of Southwestern Power Administration
(Southwestern), described generally as the States of Arkansas,
Kansas, Louisiana, Missouri, Oklahoma, and Texas.
Applicable
To wholesale Customers which have contractual rights from
Southwestern to purchase Hydro Peaking Power and associated energy
(Peaking Energy and Supplemental Peaking Energy).
Character and Conditions of Service
Three-phase, alternating current, delivered at approximately 60
Hertz, at the nominal voltage(s), at the points of delivery, and in
such quantities as are specified by contract.
Definitions of Terms
``Customer'' is the entity which is utilizing and/or purchasing
hydroelectric power and associated energy and services from
Southwestern pursuant to this rate schedule.
The ``Demand Period'' used to determine maximum integrated rates
of delivery for the purpose of power accounting is the 60-minute
period which begins with the change of hour. The term ``peak
demand'' means the highest rate of delivery, in kilowatts, for any
Demand Period during a particular month, at any particular point of
delivery.
For the purposes of this Rate Schedule, the term ``point of
delivery'' is used to mean either a single physical point at which
electric power and energy are delivered from the System of
Southwestern (defined below), or a specified set of delivery points
which together form a single, electrically integrated load. ``Peak
demand'' for such set of delivery points is computed as the
coincidental highest rate of delivery among the specified points
rather than as the sum of peak demands for each individual physical
point of delivery.
The term ``Peaking Contract Demand'' means the maximum rate in
kilowatts at which Southwestern is, by contract, obligated to
deliver Peaking Energy during any Demand Period. Unless otherwise
provided by contract, the ``Peaking Billing Demand'' for any month
shall be equal to the ``Peaking Contract Demand.''
The term ``Uncontrollable Force,'' as used herein, shall mean
any force which is not within the control of the party affected,
including, but not limited to failure of water supply, failure of
facilities, flood, earthquake, storm, lightning, fire, epidemic,
war, riot, civil disturbance, labor disturbance, sabotage, or
restraint by court of general jurisdiction, which by exercise of due
diligence and foresight such party could not reasonably have been
expected to avoid.
The term ``System of Southwestern'' means the high-voltage
transmission lines and related facilities Southwestern owns and
operates, and/or has contractual rights to such transmission
facilities owned by others.
``Ancillary Services'' are those services necessary to support
the transmission of capacity and energy from resources to loads
while maintaining reliable operation of the System of Southwestern
in accordance with good utility practice. Definitions of the
Ancillary Services are as follows:
``Scheduling, System Control, and Dispatch Service'' is provided
by Southwestern as Control Area operator and is in regard to
interchange and load-match scheduling and related system control and
dispatch functions.
``Reactive Supply and Voltage Control from Generation Sources
Service'' is provided at transmission facilities in the System of
Southwestern to produce or absorb reactive power and to maintain
transmission voltages within specific limits.
``Regulation and Frequency Response Service'' is the continuous
balancing of generation and interchange resources accomplished by
raising or lowering the output of on-line generation as necessary to
follow the moment-by-moment changes in load and to maintain
frequency within a Control Area.
``Spinning Operating Reserve Service'' maintains generating
units on-line, but loaded at less than maximum output, which may be
used to service load immediately when disturbance conditions are
experienced due to a sudden loss of generation or load.
``Supplemental Operating Reserve Service'' provides an
additional amount of operating reserve sufficient to reduce Area
Control Error to zero within 10 minutes following loss of generating
capacity which would result from the most severe single contingency.
``Energy Imbalance Service'' corrects for differences over a
period of time between schedules and actual hourly deliveries of
energy to a load. Energy delivered or received within the authorized
bandwidth (defined below) for this service is accounted for as an
inadvertent flow and is returned to the providing party by the
receiving party in accordance with standard utility practice.
Energy Associated With Hydro Peaking Power
Peaking Energy
1,200 kilowatthours of Peaking Energy per kilowatt of Peaking
Contract Demand will be furnished during each contract year.
Supplemental Peaking Energy
Supplemental Peaking Energy (in addition to Peaking Energy) will
be furnished if and when determined by Southwestern to be available,
and at rates of delivery which do not exceed the Customer's Peaking
Contract Demand.
Monthly Rates for Peaking Contract Demand
Capacity Charge for Hydro Peaking Power
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2007 10/1/2007-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
$3.03 per kilowatt of Peaking Billing $3.18 per kilowatt of $3.51 per kilowatt of Peaking Billing Demand.
Demand. Peaking Billing Demand.
----------------------------------------------------------------------------------------------------------------
[[Page 63976]]
Services Associated With Capacity Charge for Hydro Peaking Power
The capacity charge for Hydro Peaking Power includes such
transmission services as are necessary to integrate Southwestern's
resources in order to reliably deliver Hydro Peaking Power and
associated energy to Customers. This capacity charge also includes
two ancillary services charges, Scheduling, System Control and
Dispatch Service and Reactive Supply and Voltage Control from
Generation Sources Service.
Secondary Transmission Service Under Capacity Associated With Hydro
Peaking Power
Customers may utilize the capacity associated with Peaking
Contract Demand for the transmission of non-Federal energy, on a
non-firm, as-available basis, at no additional charge for such
transmission service or associated Ancillary Services, under the
following terms and conditions:
(1) The sum of the capacity, for any hour, which is used for
Peaking Energy, Supplemental Peaking Energy, and Secondary
Transmission Service, may not exceed the Peaking Contract Demand;
(2) The non-Federal energy transmitted under such secondary
service is delivered to the Customer's point of delivery for Hydro
Peaking Power;
(3) The Customer commits to provide Real Power Losses associated
with such deliveries of non-Federal energy; and
(4) Southwestern determines that sufficient transfer capability
exists between the point of receipt into the System of Southwestern
of such non-Federal energy and the Customer's point of delivery for
Hydro Peaking Power for the time period that such secondary
transmission service is requested.
Rates for Energy Associated With Hydro Peaking Power
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2007 10/1/2007-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
(a) Peaking Energy Charge
----------------------------------------------------------------------------------------------------------------
$0.0082 per kilowatthour of Peaking $0.0082 per kilowatthour $0.0082 per kilowatthour of Peaking Energy
Energy delivered; plus (c). of Peaking Energy delivered; plus (c).
delivered; plus (c).
----------------------------------------------------------------------------------------------------------------
(b) Supplemental Energy Charge
----------------------------------------------------------------------------------------------------------------
$0.0055 per kilowatthour of Peaking $0.0082 per kilowatthour $0.0082 per kilowatthour of Peaking Energy.
Energy. of Peaking Energy.
----------------------------------------------------------------------------------------------------------------
(c) A purchased power adder of $0.0067 per kilowatthour of
Peaking Energy delivered, as adjusted by the Administrator,
Southwestern, in accordance with the procedure within this rate
schedule. This adder does not apply to:
Supplemental Peaking Energy, or
Sales to any Customer which, by contract, has assumed the obligation
to supply energy to fulfill the minimum of 1,200 kilowatthours of
Peaking Energy per kilowatt of Peaking Contract Demand during a
contract year (Contract Support Arrangements).
Monthly Rates for Transformation Service
Capacity Charges for Transformation Service: A charge of $0.30
per kilowatt will be assessed for capacity used to deliver energy at
any point of delivery at which Southwestern provides transformation
service for deliveries at voltages of 69 kilovolts or less from
higher voltage facilities.
Application of Capacity Charges for Transformation Service
For any particular month, charges for transformation service
will be assessed on the greater of (1) that month's actual peak
demand, or (2) the highest peak demand recorded during the previous
11 months, at any point of delivery. For the purpose of this Rate
Schedule, the peak demand will be based on all deliveries, of both
Federal and non-Federal energy, from the System of Southwestern, at
such point during such month.
Rates for Ancillary Services
Capacity Charges for Ancillary Services
----------------------------------------------------------------------------------------------------------------
10/1/2006-9/30/2008 10/1/2008-9/30/2010
----------------------------------------------------------------------------------------------------------------
(a) Regulation and Frequency Response Service
----------------------------------------------------------------------------------------------------------------
Monthly rate........................ $0.08 per kilowatt of $0.09 per kilowatt of Peaking Billing Demand.
Peaking Billing Demand.
----------------------------------------------------------------------------------------------------------------
(b) Spinning Operating Reserve Service
----------------------------------------------------------------------------------------------------------------
Monthly rate........................ $0.0079 per kilowatt of $0.0092 per kilowatt of Peaking Billing Demand.
Peaking Billing Demand.
Daily rate.......................... $0.00036 per kilowatt $0.00042 per kilowatt for non-Federal generation
for non-Federal inside Southwestern's control area.
generation inside
Southwestern's control
area.
----------------------------------------------------------------------------------------------------------------
(c) Supplemental Operating Reserve Service
----------------------------------------------------------------------------------------------------------------
Monthly rate........................ $0.0079 per kilowatt of $0.0092 per kilowatt of Peaking Billing Demand.
Peaking Billing Demand.
Daily rate.......................... $0.00036 per kilowatt $0.00042 per kilowatt for non-Federal generation
for non-Federal inside Southwestern's control area.
generation inside
Southwestern's control
area.
----------------------------------------------------------------------------------------------------------------
(d) Energy Imbalance Service: $0.0 per kilowatt for all
reservation periods.
Availability of Ancillary Services
Ancillary Services (a) and (d) listed above are available only
for deliveries of power and energy to load centers within
Southwestern's Control Area. Ancillary Services (b) and (c) listed
above are available only for deliveries of non-Federal power and
energy generated by resources located within Southwestern's
[[Page 63977]]
Control Area and for deliveries of all Hydro Peaking Power and
associated energy from and within Southwestern's Control Area. Where
available, such Ancillary Services must be taken from Southwestern;
unless, subject to Southwestern's approval, they are provided by
others.
Application of Ancillary Services Charges
For any month, the charges for Ancillary Services (a), (b), (c)
and (d) listed above for deliveries of Hydro Peaking Power shall be
based on the Peaking Billing Demand.
The daily charge for Ancillary Services (b) and (c) for non-
Federal generation inside Southwestern's Control Area shall be
applied to the greater of Southwestern's previous day's estimate of
the peak, or the actual peak, in kilowatts, of the internal non-
Federal generation.
Provision of Ancillary Services by Others
Customers for which Ancillary Services (a), (b), (c) and (d) are
made available as specified above, must inform Southwestern by
written notice of the Ancillary Services which they do not intend to
take and purchase from Southwestern, and of their election to
provide all or part of such Ancillary Services from their own
resources or from a third party.
Subject to Southwestern's approval of the ability of such
resources or third parties to meet Southwestern's technical
requirements for provision of such Ancillary Services, the Customer
may change the Ancillary Services which it takes from Southwestern
and/or from other sources at the beginning of any month upon the
greater of 60 days notice or upon completion of any necessary
equipment modifications necessary to accommodate such change.
Limitations on Energy Imbalance Service
Energy Imbalance Service primarily applies to deliveries of
power and energy which are required to satisfy a Customer's load. As
Hydro Peaking Power and associated energy are limited by contract,
the Energy Imbalance Service bandwidth specified in Southwestern's
Open Access Transmission Service tariff does not apply to deliveries
of Hydro Peaking Power, and therefore Energy Imbalance Service is
not charged on such deliveries. Customers who consume a capacity of
Hydro Peaking Power greater than their Peaking Contract Demand may
be subject to a Capacity Overrun Penalty.
Application of Capacity Overrun Penalty
Customers which have loads within Southwestern's Control Area
are obligated by contract to provide resources, over and above the
Hydro Peaking Power and associated energy purchased from
Southwestern, sufficient to meet their loads. A Capacity Overrun
Penalty shall be applied only when the formulas provided in
Customers' contracts indicate an overrun on Hydro Peaking Power, and
investigation determines that all resources, both firm and non-firm,
which were available at the time of the apparent overrun were
insufficient to meet the Customer's load.
Capacity Overrun Penalty
For each hour during which Hydro Peaking Power was provided at a
rate greater than that to which the Customer is entitled, the
Customer will be charged a capacity overrun penalty at the following
rates:
------------------------------------------------------------------------
