Revised Public Utility Filing Requirements for Electric Quarterly Reports, 1876-1889 [E8-184]
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
(866) 208–3676 (toll free). For TTY, call
(202) 502–8659.
Comment Date: 5 p.m. Eastern Time
on January 22, 2008.
Kimberly D. Bose,
Secretary.
[FR Doc. E8–235 Filed 1–9–08; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. EL08–22–000]
Missouri River Energy Services;
Western Minnesota Municipal Power
Agency; Notice of Filing
yshivers on PROD1PC62 with NOTICES
December 31, 2007.
Take notice that on December 20,
2007, pursuant to Rule 207(a)(2) and
Rule 2004 of the Rules of Practices and
Procedure of the Federal Energy
Regulatory Commission, 18 CFR
385.207(a)(2) and 385.2004 (2006),
Missouri River Energy Services (MRES)
and Western Minnesota Municipal
Power Agency (Western Minnesota)
filed a petition for declaratory order
permitting MRES and Western
Minnesota to combine their financial
information for purposes of the
variances being sought by MRES to the
Attachment O transmission formula
under the Midwest Independent
Transmission System Operator, Inc.’s
Open Access Transmission and Energy
Markets Tariff. MRES and Western
Minnesota also submit an exemption of
the application fee, pursuant to section
381.108 of the Commission’s Rules and
Regulations.
Any person desiring to intervene or to
protest this filing must file in
accordance with Rules 211 and 214 of
the Commission’s Rules of Practice and
Procedure (18 CFR 385.211, 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
comment date. On or before the
comment date, it is not necessary to
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
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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 January 22, 2008.
Kimberly D. Bose,
Secretary.
[FR Doc. E8–236 Filed 1–9–08; 8:45 am]
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 January 22, 2008.
Kimberly D. Bose,
Secretary.
[FR Doc. E8–230 Filed 1–9–08; 8:45 am]
BILLING CODE 6717–01–P
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
Federal Energy Regulatory
Commission
[Docket No. RM01–8–007]
[Docket No. EL08–28–000]
City of Pasadena, CA; Notice of Filing
Revised Public Utility Filing
Requirements for Electric Quarterly
Reports
December 31, 2007.
December 21, 2007.
Take notice that on December 21,
2007, the City of Pasadena, California,
filed its third annual revision to its
Transmission Revenue Balancing
Account Adjustment, to become
effective January 1, 2008.
Any person desiring to intervene or to
protest this filing must file in
accordance with Rules 211 and 214 of
the Commission’s Rules of Practice and
Procedure (18 CFR 385.211, 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
comment date. On or before the
comment date, it is not necessary to
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,
SUMMARY: In this order, the Federal
Energy Regulatory Commission
(Commission) grants in part, and denies
in part, rehearing and clarifies the
information to be reported in the
Electric Quarterly Report’s (EQR’S)
fields for Contract Execution Date (Field
No. 21), Contract Commencement Date
(Field No. 22) and Rate Description
(Field No. 37). In addition, the order
corrects an error relating to Increment
Name (Field Nos. 28 and 60).
DATES: This order becomes effective
upon issuance. The revised definitions
adopted in this order shall be applied to
EQR filings beginning with the Q1 2008
EQR (due on April 30, 2008) and in
subsequent EQR filings due thereafter.
FOR FURTHER INFORMATION CONTACT:
Michelle Veloso (Technical
Information), Office of Enforcement,
Federal Energy Regulatory Commission,
888 First Street, NE., Washington, DC
20426, (202) 502–8363.
Gary D. Cohen (Legal Information),
Office of the General Counsel, Federal
Energy Regulatory Commission, 888
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Federal Energy Regulatory
Commission, Department of Energy.
ACTION: Order No. 2001–H; Order on
Rehearing and Clarification.
AGENCY:
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
First Street, NE., Washington, DC 20426,
(202) 502–8321.
SUPPLEMENTARY INFORMATION:
Before Commissioners: Joseph T.
Kelliher, Chairman; Suedeen G. Kelly,
Marc Spitzer, Philip D. Moeller, and Jon
Wellinghoff.
1. On October 24, 2007, Edison
Electric Institute (EEI) filed a request for
rehearing or clarification in response to
the Commission’s order adopting an
Electric Quarterly Report (EQR) Data
Dictionary.1 Order No. 2001–G collected
in one document the definitions of
certain terms and values used in filing
EQR data (previously provided in
Commission orders and in guidance
materials posted at the Commission’s
website) and issued formal definitions
for fields that were previously
undefined.2 In this order, the
Commission grants in part, and denies
in part, rehearing and clarifies the
information to be reported in Contract
Execution Date (Field No. 21), Contract
Commencement Date (Field No. 22) and
Rate Description (Field No. 37). In
addition, we correct an error that we
made in Order No. 2001–G relating to
Increment Name (Field Nos. 28 and 60).
II. Discussion
I. Background
yshivers on PROD1PC62 with NOTICES
2. On April 25, 2002, the Commission
issued Order No. 2001, a Final Rule
establishing revised public utility filing
requirements.3 This rule revised the
Commission’s filing requirements to
require companies subject to the
Commission’s regulations under section
205 of the Federal Power Act to file
quarterly reports that: (1) Provide data
identifying the utility on whose behalf
the report is being filed (ID Data); (2)
summarize pertinent data about the
utility’s currently effective contracts
(Contract Data); and (3) summarize data
about wholesale power sales the utility
made during the reporting period
(Transaction Data). The requirement to
file EQRs replaced the requirement to
file quarterly transaction reports
summarizing a utility’s market-based
rate transactions and sales agreements
that conformed to the utility’s tariff.
1 Revised Public Utility Filing Requirements for
Electric Quarterly Reports, Order No. 2001–G, 120
FERC ¶ 61,270 (Sep. 24, 2007), 72 FR 56735 (Oct.
4, 2007).
2 Id.
3 Revised Public Utility Filing Requirements for,
Order No. 2001, 67 FR 31043, FERC Stats. & Regs.
¶ 31,127 (2002), reh’g denied, Order No. 2001–A,
100 FERC ¶ 61,074, reconsideration and
clarification denied, Order No. 2001–B, 100 FERC
¶ 61,342, order directing filings, Order No. 2001–
C, 101 FERC ¶ 61,314 (2002), order directing filings,
Order No. 2001–D, 102 FERC ( 61,334, order
refining filing requirements, Order No. 2001–E, 105
FERC ¶ 61,352 (2003), clarification order, Order No.
2001–F, 106 FERC ¶ 61,060 (2004).
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3. In Order No. 2001, the Commission
also adopted a new section in its
regulations, 18 CFR 35.10b, which
requires that the EQRs are to be
prepared in conformance with the
Commission’s software and guidance
posted and available from the
Commission website. This obviates the
need to revise section 35.10b to
implement revisions to the software and
guidance. Since the issuance of Order
No. 2001, as need has arisen, the
Commission has issued orders to resolve
questions raised by EQR users and has
directed Staff to issue additional
guidance.4
4. On September 24, 2007, the
Commission issued Order No. 2001–G,
providing a data dictionary to clarify the
information to be reported in EQR data.
EEI filed a request for rehearing or
clarification requesting clarification of a
few specific items. In addition, on
December 4, 2007, TransAlta filed
comments alerting the Commission to a
filing problem it was experiencing
relating to Increment Name (Field Nos.
28 and 60). The discussion below
addresses EEI’s rehearing request and
TransAlta’s comments.
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A. Field No. 21—Contract Execution
Date
5. The EQR Notice 5 proposed only a
slight change to the Order No. 2001
definition for Contract Execution Date:
‘‘The date the contract was signed. If the
parties signed on different dates, or
there are contract amendments, use the
most recent date signed.’’
6. In response to the EQR Notice,
Reliant and EEI suggested that the
Contract Execution Date should not
change because of a minor amendment
to the contract. Both commenters noted
that, frequently, contract amendments
are minor changes, such as changes in
an address or in payment terms, that do
not affect the key operational
parameters of the agreement.
7. Based on these comments, the
Commission found in Order No. 2001–
G that the usefulness of the data may be
increased with a single execution date
for each contract across all periods.
However, the order explained that, if
there are material amendments to the
contract, then the Contract Execution
Date must be changed.
8. In EEI’s request for rehearing, it
argues that the Commission’s
instruction that the Contract Execution
Date must be changed when there are
4 Examples
cited in EQR Notice at P 3.
5 Notice Seeking Comments on Proposed Electric
Quarterly Report Data Dictionary, FERC Stats. &
Regs. ¶ 35,050 (2007), 72 FR 26091 (May 8, 2007).
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material amendments to the contract is
confusing and burdensome. It suggests
that the original execution date should
be reported for the duration of the
contract and argues that changes in the
contract will be reflected in the
descriptions of revised contract
provisions, such as in the Rate (Field
No. 34), Begin Date (Field No. 43) and
End Date fields (Field No. 44).
Commission Conclusion
9. In Order No. 2001–G, the
Commission agreed with EEI and
Reliant that it need not change the
Contract Execution Date each time there
is a minor revision to the contract and,
accordingly, modified the instructions
on what information should be reported
in this field. The Commission reduced
the burden and confusion by clarifying
that minor, non-material changes may
be omitted for the purpose of identifying
the Contract Execution Date. EEI argues
that the Contract Execution Date should
not be revised, even in instances where
there has been a material amendment to
the contract.
10. The Commission recognizes the
benefits of classifying a contractual
relationship based on when it originated
and will revise the definition of
Contract Execution Date as EEI suggests
to require companies to report the
original date the contract was executed,
without regard to any subsequent
revisions to the contract. For the
purposes of the EQR Data Dictionary,
the definition will read: ‘‘The date the
contract was signed. If the parties signed
on different dates, use the most recent
date signed.’’ However, this change will
not be incorporated at the cost of
obscuring information that would alert
EQR users that key terms in the contract
have been revised. Thus, the
Commission will revise the definition of
Contract Commencement Date as
described below.
B. Field No. 22—Contract
Commencement Date
11. In order to alert EQR users that a
contract has been revised, the
Commission will revise the definition of
Contract Commencement Date to refer to
the date that service commenced under
the current terms and conditions of the
contract. The Commission will further
clarify that the terms deemed relevant
for determining or changing the
Contract Commencement Date are those
that are reported in the Contract Data
section of the EQR.6 Any amendment
6 In developing the EQR, the Commission
identified a number of key terms associated with
the products and services offered under any given
jurisdictional contract. These terms include: Class
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
that would cause a change in these
required data elements would require a
change in the Contract Commencement
Date.
12. The Commission recognizes EEI’s
concern regarding potential
inconsistency between the EQR and
eTariff in identifying an original
execution date. However, there is a very
real public interest in identifying when
key terms of the contract were
determined. As market conditions
change over time, it is imperative to be
able to sort the deals that occurred years
ago from those that were confirmed
more recently. To better understand the
market conditions at the time a contract
was put in place, it is necessary to
document the date that key terms were
established.
13. The Commission will define
Contract Commencement Date as ‘‘The
date the terms of the contract reported
in the EQR were effective. If the terms
reported in the Contract Data section of
the EQR became effective or if service
under those terms began on multiple
dates (i.e.: due to an amendment), the
date to be reported as the
Commencement Date is the date when
service began pursuant to the most
recent amendment to the terms reported
in the Contract Data section of the
EQR.’’ In this way, the Commission and
the public will continue to be able to
determine when the contract terms
reported in the EQR were determined.
yshivers on PROD1PC62 with NOTICES
C. Field Nos. 28 and 60—Increment
Name
14. In the EQR Notice,7 the
Commission proposed to revise Field
Nos. 28 and 60 to, among other matters,
create an Increment Name covering
‘‘Seasonal’’ sales to characterize power
sales made for longer than one month,
but less than a year.8 This proposal was
opposed in comments filed by EEI,
Reliant and Occidental. In Order No.
Name, Term Name, Increment Name, Increment
Peaking Name, Increment Peaking Name, Product
Type Name, Product Name, Rate (actual, maximum,
minimum or description), and Time Zone. The
Commission requires that Class Name, Term Name,
Increment Name, Increment Peaking Name, Product
Type Name, Product Name, and Time Zone be
reported in the EQR for every product offered under
every jurisdictional contract. Additionally, the
Commission requires a definition of the rate for
every product either as a Rate, a Rate Minimum, a
Rate Maximum or a Rate Description. Finally, the
Commission requires that companies report, when
specified in the contract for a given product,
Quantity, Units, Rate Units, Point of Receipt
Control Area, Point of Receipt Specific Location,
Point of Delivery Control Area, Point of Delivery
Specific Location, Begin Date, and End Date.
7 Revised Public Utility Filing Requirements for
Electric Quarterly Reports, 72 Fed. Reg. 26091 (May
8, 2007), FERC Stats. & Regs. ¶ 35,050 (2007) (EQR
Notice).
8 EQR Notice at P. 18.
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2001–G, the Commission agreed with
the commenters that the term ‘‘S—
Seasonal’’ should not be included in the
options available for the Increment
Name fields. However, in the issued
Order No. 2001–G, when the term
‘‘Seasonal’’ was dropped from the Data
Dictionary, the interval to be included
in ‘‘Monthly’’ should have been
adjusted in the attached Data
Dictionary, so there would be no gap
between ‘‘Monthly’’ and ‘‘Annual.’’
Unfortunately, this correction was
inadvertently omitted.
15. On December 4, 2007, TransAlta
filed comments alerting the Commission
to this problem.
Commission Conclusion
16. We will take this opportunity to
correct the inadvertent error in Order
No. 2001–G involving Increment Name,
so that filers can accurately report their
sales covering a period of more than 168
consecutive hours up to one year as MMonthly (>168 consecutive hours and <
1 year).
D. Field No. 37—Rate Description
17. The EQR Notice proposed
defining Rate Description as a ‘‘[t]ext
description of rate. May reference FERC
tariff, or, if a discounted or negotiated
rate, include algorithm.’’ EEI filed
comments in response to the EQR
Notice requesting that filers be allowed
to enter the tariff location into the Rate
Description field in lieu of a detailed
description of the rate itself. EEI
supported this request by citing the
difficulty of putting complex rates into
the 150 character field. In Order No.
2001–G, the Commission stated that the
EQR fulfills the Commission’s statutory
obligation under the Federal Power Act
(FPA) to have companies’ rates on file.
We further stated that the Commission
relies on the EQR to satisfy the FPA
requirement that rates provided in a
contract be publicly disclosed and on
file. Thus, we concluded that it is
imperative that the information reported
in EQRs provide an adequate level of
detail and transparency.
18. The Commission also stated in
Order No. 2001–G that a tariff reference
alone, instead of the actual rate
description, does not meet the FPA
standard. Allowing filers to substitute a
tariff reference in place of an actual rate
description would force EQR users
seeking this information to conduct
further research to track down the
contents of the tariff on file. This is
clearly less transparent than a rate
description that actually describes the
rate. We also explained that, if the tariff
reference is coupled with a descriptive
summary of the rate, where the rate is
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the function of a complex algorithm, the
standard is met. Further, we explained
that rate information will continue to be
available to the public at a level
sufficient to explain the bases and
methods of calculation with additional
detail available upon request to
interested persons.
19. On rehearing, EEI argues that, in
the case of cost-based rates, the FPA
requirement that rates be on file is
satisfied by separate on-the-record
Commission filings, so it is not
necessary to provide a rate description
in the EQR to satisfy the FPA. Thus, it
argues, a reference to the rate schedule
number and page is sufficient for EQR
purposes, without any text description
of the rate.
Commission Conclusion
20. Prior to the adoption of Order No.
2001, public utilities satisfied the FPA
requirement to have their rates on file
with the Commission without filing
EQRs (which had not yet been
established). Thus, EEI is correct that
the EQR filings are not the sole means
by which this legal requirement can be
met. However, section 205(c) provides
the Commission with wide discretion
on how companies are to file their rates
and, in Order No. 2001, the Commission
established the EQR as a means to
ensure compliance with the FPA, and to
provide a mechanism for the public to
inspect and review the pertinent terms
and conditions of public utilities’
contracts and transactions in an
electronic format that afforded greater
transparency and accessibility to this
information.9
21. When this issue first was
considered in Order No. 2001–G, it
centered on the question of whether 150
characters would be sufficient to
provide all the information needed to
accurately describe a public utility’s
rates. After consideration of EEI’s
arguments and the problem of fitting an
accurate rate description into 150
characters without sacrificing
transparency, we are persuaded to
revise the definition for Rate
Description to include a provision that
relates to a rate that is currently on file
with the Commission. The Commission
will define Rate Description as ‘‘[t]ext
description of rate. If the rate is
currently available on the FERC Web
site, a citation of the FERC Accession
Number and the relevant FERC tariff
including page number or section may
be included instead of providing the
entire rate algorithm. If the rate is not
available on the FERC Web site, include
the rate algorithm, if rate is calculated.
9 See,
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for example, Order No. 2001 at P. 95.
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
If the algorithm would exceed the 150
character field limit, it may be provided
in a descriptive summary (including
bases and methods of calculations) with
a detailed citation of the relevant FERC
tariff including page number and
section. If more than 150 characters are
required, the contract product may be
repeated in subsequent lines of data
until the rate is adequately described.’’
With this revision of Rate Description,
EQR filers may provide the necessary
information without sacrificing
transparency.
III. Document Availability
22. In addition to publishing the full
text of this document in the Federal
Register, the Commission provides all
interested persons an opportunity to
view and/or print the contents of this
document via the Internet through the
Commission’s Home Page (https://
www.ferc.gov) and in the Commission’s
Public Reference Room during normal
business hours (8:30 a.m. to 5 p.m.
Eastern time) at 888 First Street, NE.,
Room 2A, Washington, DC 20426.
23. From the Commission’s Home
Page on the Internet, this information is
available in the eLibrary. The full text
of this document is available in the
eLibrary both in PDF and Microsoft
Word format for viewing, printing, and/
or downloading. To access this
document in eLibrary, type ‘‘RM01–8’’
in the docket number field. User
assistance is available for eLibrary and
the Commission’s website during the
Commission’s normal business hours.
For assistance contact the Commission’s
Online Support services at
FERCOnlineSupport@ferc.gov or toll-
1879
free at (866) 208–3676, or for TTY,
contact (202) 502–8659.
The Commission orders:
(A) EEI’s request for rehearing or
clarification is hereby granted in part,
and denied in part, as discussed in the
body of this order.
(B) TransAlta’s request for
clarification is hereby granted, as
discussed in the body of this order.
(C) The revised definitions adopted in
this order shall be applied to EQR
filings beginning with the Q1 2008 EQR
(due on April 30, 2008) and in
subsequent EQR filings due thereafter.
By the Commission.
Kimberly D. Bose,
Secretary.
Attachment
Electric Quarterly Report Data
Dictionary Version 1.0 (Issued —)
EQR DATA DICTIONARY
Field
No.
Field
Required
Value
Definition
ID Data
Filer Unique Identifier.
............................
FR1 ........................
1 ..........
Filer Unique Identifier.
............................
FS# (where ‘‘#’’ is
an integer).
1 ..........
Filer Unique Identifier.
............................
FA1 ........................
2 ..........
Company Name .....
............................
Unrestricted text
(100 characters).
2 ..........
Company Name .....
............................
Unrestricted text
(100 characters).
2 ..........
Company Name .....
............................
Unrestricted text
(100 characters).
3 ..........
Company DUNS
Number.
Contact Name ........
for Respondent and
Seller.
............................
Nine digit number ..
4 ..........
4 ..........
Contact Name ........
............................
Unrestricted text
(50 characters).
4 ..........
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1 ..........
Contact Name ........
............................
5 ..........
Contact Title ...........
............................
6 ..........
7 ..........
Contact Address ....
Contact City ...........
............................
............................
8 ..........
Contact State .........
............................
Unrestricted text
(50 characters).
Unrestricted text
(50 characters).
Unrestricted text .....
Unrestricted text
(30 characters).
Unrestricted text (2
characters).
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Unrestricted text
(50 characters).
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(Respondent)—An identifier (i.e., ‘‘FR1’’) used to designate a
record containing Respondent identification information in a
comma-delimited (csv) file that is imported into the EQR filing.
Only one record with the FR1 identifier may be imported into an
EQR for a given quarter.
(Seller)—An identifier (e.g., ‘‘FS1’’, ‘‘FS2’’) used to designate a
record containing Seller identification information in a commadelimited (csv) file that is imported into the EQR filing. One
record for each seller company may be imported into an EQR
for a given quarter.
(Agent)—An identifier (i.e., ‘‘FA1’’) used to designate a record containing Agent identification information in a comma-delimited
(csv) file that is imported into the EQR filing. Only one record
with the FA1 identifier may be imported into an EQR for a given
quarter.
(Respondent)—The name of the company taking responsibility for
complying with the Commission’s regulations related to the
EQR.
(Seller)—The name of the company that is authorized to make
sales as indicated in the company’s FERC tariff(s). This name
may be the same as the Company Name of the Respondent.
(Agent)—The name of the entity completing the EQR filing. The
Agent’s Company Name need not be the name of the company
under Commission jurisdiction.
The unique nine digit number assigned by Dun and Bradstreet to
the company identified in Field Number 2.
(Respondent)—Name of the person at the Respondent’s company
taking responsibility for compliance with the Commission’s EQR
regulations.
(Seller)—The name of the contact for the company authorized to
make sales as indicated in the company’s FERC tariff(s). This
name may be the same as the Contact Name of the Respondent.
(Agent)—Name of the contact for the Agent, usually the person
who prepares the filing.
Title of contact identified in Field Number 4.
Street address for contact identified in Field Number 4.
City for the contact identified in Field Number 4.
Two character state or province abbreviations for the contact identified in Field Number 4.
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EQR DATA DICTIONARY—Continued
Field
No.
Field
Required
Value
9 ..........
Contact Zip ............
............................
10 ........
Contact Country
Name.
............................
11 ........
Contact Phone .......
............................
12 ........
13 ........
Contact E-Mail .......
Filing Quarter .........
............................
............................
Unrestricted text
(10 characters).
CA—Canada ..........
MX—Mexico
US—United States
UK—United Kingdom.
Unrestricted text
(20 characters).
Unrestricted text .....
YYYYMM ...............
Definition
Zip code for the contact identified in Field Number 4.
Country (USA, Canada, Mexico, or United Kingdom) for contact
address identified in Field Number 4.
Phone number of contact identified in Field Number 4.
E-mail address of contact identified in Field Number 4.
A six digit reference number used by the EQR software to indicate
the quarter and year of the filing for the purpose of importing
data from csv files. The first 4 numbers represent the year (e.g.,
2007). The last 2 numbers represent the last month of the quarter (e.g., 03 = 1st quarter; 06 = 2nd quarter, 09 = 3rd quarter,
12 = 4th quarter).
Contract Data
14 ........
Contract Unique ID
............................
15 ........
Seller Company
Name.
............................
16 ........
Customer Company
Name.
Customer DUNS
Number.
Contract Affiliate ....
............................
............................
Y (Yes) ...................
N (No) ....................
19 ........
FERC Tariff Reference.
............................
Unrestricted text
(60 characters).
20 ........
Contract Service
Agreement ID.
............................
Unrestricted text
(30 characters).
21 ........
Contract Execution
Date.
Contract Commencement Date.
............................
YYYYMMDD ..........
............................
YYYYMMDD ..........
Contract Termination Date.
Actual Termination
Date.
Extension Provision
Description.
Class Name ...........
Class Name ...........
If specified in the
contract.
If contract terminated.
............................
YYYYMMDD ..........
The unique nine digit number assigned by Dun and Bradstreet to
the company identified in Field Number 16.
The customer is an affiliate if it controls, is controlled by or is
under common control with the seller. This includes a division
that operates as a functional unit. A customer of a seller who is
an Exempt Wholesale Generator may be defined as an affiliate
under the Public Utility Holding Company Act and the FPA.
The FERC tariff reference cites the document that specifies the
terms and conditions under which a Seller is authorized to make
transmission sales, power sales or sales of related jurisdictional
services at cost-based rates or at market-based rates. If the
sales are market-based, the tariff that is specified in the FERC
order granting the Seller Market Based Rate Authority must be
listed.
Unique identifier given to each service agreement that can be
used by the filing company to produce the agreement, if requested. The identifier may be the number assigned by FERC
for those service agreements that have been filed with and accepted by the Commission, or it may be generated as part of an
internal identification system.
The date the contract was signed. If the parties signed on different
dates, use the most recent date signed.
The date the terms of the contract reported in the EQR were effective. If the terms reported in the Contract Data section of the
EQR became effective or if service under those terms began on
multiple dates (i.e.: due to an amendment), the date to be reported as the Commencement Date is the date when service
began pursuant to the most recent amendment to the terms reported in the Contract Data section of the EQR.
The date that the contract expires.
YYYYMMDD ..........
The date the contract actually terminates.
Unrestricted text .....
............................
............................
................................
F—Firm ..................
Description of terms that provide for the continuation of the contract.
See definitions of each class name below.
For transmission sales, a service or product that always has priority over non-firm service. For power sales, a service or product
that is not interruptible for economic reasons.
17 ........
18 ........
22 ........
23 ........
yshivers on PROD1PC62 with NOTICES
24 ........
25 ........
26 ........
26 ........
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An integer proceeded by the
letter ‘‘C’’ (only
used when importing contract
data)
Unrestricted text
(100 characters).
Unrestricted text
(70 characters).
Nine digit number ..
Frm 00019
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An identifier beginning with the letter ‘‘C’’ and followed by a number (e.g., ‘‘C1’’, ‘‘C2’’) used to designate a record containing
contract information in a comma-delimited (csv) file that is imported into the EQR filing. One record for each contract product
may be imported into an EQR for a given quarter.
The name of the company that is authorized to make sales as indicated in the company’s FERC tariff(s). This name must match
the name provided as a Seller’s ‘‘Company Name’’ in Field
Number 2 of the ID Data (Seller Data).
The name of the counterparty.
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
1881
EQR DATA DICTIONARY—Continued
Field
No.
Field
Required
Value
Definition
26 ........
Class Name ...........
............................
NF—Non-firm .........
26 ........
Class Name ...........
............................
26 ........
Class Name ...........
............................
27 ........
Term Name ............
............................
28 ........
28 ........
Increment Name ....
Increment Name ....
............................
............................
UP—Unit Power
Sale.
N/A—Not Applicable.
LT—Long Term ......
ST—Short Term .....
N/A—Not Applicable.
................................
H—Hourly ..............
For transmission sales, a service that is reserved and/or scheduled on an as-available basis and is subject to curtailment or
interruption at a lesser priority compared to Firm service. For an
energy sale, a service or product for which delivery or receipt of
the energy may be interrupted for any reason or no reason,
without liability on the part of either the buyer or seller.
Designates a dedicated sale of energy and capacity from one or
more than one specified generation unit(s).
To be used only when the other available Class Names do not
apply.
Contracts with durations of one year or greater are long-term.
Contracts with shorter durations are short-term.
28 ........
Increment Name ....
............................
D—Daily .................
28 ........
Increment Name ....
............................
W—Weekly ............
28 ........
Increment Name ....
............................
M—Monthly ............
28 ........
Increment Name ....
............................
Y—Yearly ...............
28 ........
Increment Name ....
............................
29 ........
Increment Peaking
Name.
Increment Peaking
Name.
............................
N/A—Not Applicable.
................................
............................
FP—Full Period .....
............................
OP—Off-Peak ........
............................
P—Peak .................
............................
30 ........
30 ........
Increment Peaking
Name.
Increment Peaking
Name.
Increment Peaking
Name.
Product Type Name
Product Type Name
N/A—Not Applicable.
................................
CB—Cost Based ....
30 ........
Product Type Name
............................
30 ........
Product Type Name
............................
CR—Capacity Reassignment.
MB—Market Based
30 ........
30 ........
Product Type Name
Product Type Name
............................
............................
T—Transmission ....
Other ......................
31 ........
Product Name ........
............................
32 ........
Quantity .................
33 ........
Units .......................
34 ........
Rate .......................
If specified in the
contract.
If specified in the
contract.
................................
35 ........
Rate Minimum ........
See Product Name
Table, Appendix
A.
Number with up to
4 decimals.
See Units Table,
Appendix E.
Number with up to
4 decimals.
Number with up to
4 decimals.
36 ........
Rate Maximum ......
29 ........
29 ........
29 ........
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29 ........
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............................
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................................
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See definitions for each increment below.
Terms of the contract (if specifically noted in the contract) set for
up to 6 consecutive hours (≤ 6 consecutive hours).
Terms of the contract (if specifically noted in the contract) set for
more than 6 and up to 60 consecutive hours (> 6 and ≤ 60 consecutive hours).
Terms of the contract (if specifically noted in the contract) set for
over 60 consecutive hours and up to 168 consecutive hours
(> 60 and ≤ 168 consecutive hours).
Terms of the contract (if specifically noted in the contract) set for
more than 168 consecutive hours up to, but not including, one
year (> 168 consecutive hours and < 1 year).
Terms of the contract (if specifically noted in the contract) set for
one year or more (≥ 1 year).
Terms of the contract do not specify an increment.
See definitions for each increment peaking name below.
The product described may be sold during those hours designated
as on-peak and off-peak in the NERC region of the point of delivery.
The product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery.
The product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery.
To be used only when the increment peaking name is not specified in the contract.
See definitions for each product type below.
Energy or capacity sold under a FERC-approved cost-based rate
tariff.
An agreement under which a transmission provider sells, assigns
or transfers all or portion of its rights to an eligible customer.
Energy or capacity sold under the seller’s FERC-approved marketbased rate tariff.
The product is sold under a FERC-approved transmission tariff.
The product cannot be characterized by the other product type
names.
Description of product being offered.
Quantity for the contract product identified.
Measure stated in the contract for the product sold.
The charge for the product per unit as stated in the contract.
Maximum rate to be charged per the contract, if a range is specified.
Maximum rate to be charged per the contract, if a range is specified.
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EQR DATA DICTIONARY—Continued
Field
No.
Field
37 ........
Rate Description ....
38 ........
Rate Units ..............
If specified in the
contract.
39 ........
Point of Receipt
Balancing Authority (PORBA).
If specified in the
contract.
40 ........
Point of Receipt
Specific Location
(PORSL).
If specified in the
contract.
41 ........
Point of Delivery
Balancing Authority (PODBA).
If specified in the
contract.
42 ........
Point of Delivery
Specific Location
(PODSL).
If specified in the
contract.
43 ........
Begin Date .............
44 ........
End Date ................
45 ........
Time Zone .............
If specified in the
contract.
If specified in the
contract.
............................
Required
Value
Definition
Unrestricted text .....
Text description of rate. If the rate is currently available on the
FERC Web site, a citation of the FERC Accession Number and
the relevant FERC tariff including page number or section may
be included instead of providing the entire rate algorithm. If the
rate is not available on the FERC Web site, include the rate algorithm, if rate is calculated. If the algorithm would exceed the
150 character field limit, it may be provided in a descriptive summary (including bases and methods of calculations) with a detailed citation of the relevant FERC tariff including page number
and section. If more than 150 characters are required, the contract product may be repeated in a subsequent line of data until
the rate is adequately described.
Measure stated in the contract for the product sold.
See Rate Units
Table, Appendix
F.
See Balancing Authority Table, Appendix B.
Unrestricted text
(50 characters). If
‘‘HUB’’ is selected for
PORCA, see Hub
Table, Appendix
C.
See Balancing Authority Table, Appendix B.
Unrestricted text
(50 characters). If
‘‘HUB’’ is selected for
PODCA, see Hub
Table, Appendix
C.
YYYYMMDDHHMM
The registered NERC Balancing Authority (formerly called NERC
Control Area) where service begins for a transmission or transmission-related jurisdictional sale. The Balancing Authority will
be identified with the abbreviation used in OASIS applications. If
receipt occurs at a trading hub specified in the EQR software,
the term ‘‘Hub’’ should be used.
The specific location at which the product is received if designated
in the contract. If receipt occurs at a trading hub, a standardized
hub name must be used. If more points of receipt are listed in
the contract than can fit into the 50 character space, a description of the collection of points may be used. ‘Various,’ alone, is
unacceptable unless the contract itself uses that terminology.
The registered NERC Balancing Authority (formerly called NERC
Control Area) where a jurisdictional product is delivered and/or
service ends for a transmission or transmission-related jurisdictional sale. The Balancing Authority will be identified with the abbreviation used in OASIS applications. If delivery occurs at the
interconnection of two control areas, the control area that the
product is entering should be used. If delivery occurs at a trading hub specified in the EQR software, the term ‘‘Hub’’ should
be used.
The specific location at which the product is delivered if designated in the contract. If receipt occurs at a trading hub, a
standardized hub name must be used.
First date for the sale of the product at the rate specified.
YYYYMMDDHHMM
Last date for the sale of the product at the rate specified.
See Time Zone
Table, Appendix
D.
The time zone in which the sales will be made under the contract.
Transaction Data
Transaction Unique
ID.
............................
An integer proceeded by the
letter ‘‘T’’ (only
used when importing transaction data).
47 ........
yshivers on PROD1PC62 with NOTICES
46 ........
Seller Company
Name.
............................
Unrestricted text
(100 Characters).
48 ........
Customer Company
Name.
Customer DUNS
Number.
............................
Unrestricted text
(70 Characters).
Nine digit number ..
49 ........
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An identifier beginning with the letter ‘‘T’’ and followed by a number (e.g., ‘‘T1’’, ‘‘T2’’) used to designate a record containing
transaction information in a comma-delimited (csv) file that is imported into the EQR filing. One record for each transaction
record may be imported into an EQR for a given quarter. A new
transaction record must be used every time a price changes in a
sale.
The name of the company that is authorized to make sales as indicated in the company’s FERC tariff(s). This name must match
the name provided as a Seller’s ‘‘Company Name’’ in Field 2 of
the ID Data (Seller Data).
The name of the counterparty.
The unique nine digit number assigned by Dun and Bradstreet to
the counterparty to the contract.
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1883
EQR DATA DICTIONARY—Continued
Field
No.
Field
Required
Value
Definition
FERC Tariff Reference.
............................
Unrestricted text
(60 Characters).
51 ........
Contract Service
Agreement ID.
............................
Unrestricted text
(30 Characters).
52 ........
Transaction Unique
Identifier.
Transaction Begin
Date.
............................
53 ........
54 ........
Transaction End
Date.
............................
55 ........
Time Zone .............
............................
56 ........
Point of Delivery
Balancing Authority (PODBA).
Point of Delivery
Specific Location
(PODSL).
............................
57 ........
58 ........
58 ........
Class Name ...........
Class Name ...........
............................
............................
Unrestricted text
(24 Characters).
YYYYMMDDHHMM
(csv import).
MMDDYYYYHHMM
(manual entry).
YYYYMMDDHHMM
(csv import).
MMDDYYYYHHMM
(manual entry).
See Time Zone
Table, Appendix
D.
See Balancing Authority Table, Appendix B.
Unrestricted text
(50 characters). If
‘‘HUB’’ is selected for
PODBA, see Hub
Table, Appendix
C.
................................
F—Firm ..................
58 ........
Class Name ...........
............................
NF—Non-firm .........
58 ........
Class Name ...........
............................
58 ........
Class Name ...........
............................
UP—Unit Power
Sale.
BA—Billing Adjustment.
58 ........
Class Name ...........
............................
59 ........
Term Name ............
............................
60 ........
60 ........
Increment Name ....
Increment Name ....
............................
............................
N/A—Not Applicable.
LT—Long Term ......
ST—Short Term .....
N/A—Not Applicable.
................................
H—Hourly ..............
60 ........
Increment Name ....
............................
D—Daily .................
60 ........
yshivers on PROD1PC62 with NOTICES
50 ........
Increment Name ....
............................
W—Weekly ............
60 ........
Increment Name ....
............................
M—Monthly ............
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............................
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The FERC tariff reference cites the document that specifies the
terms and conditions under which a Seller is authorized to make
transmission sales, power sales or sales of related jurisdictional
services at cost-based rates or at market-based rates. If the
sales are market-based, the tariff that is specified in the FERC
order granting the Seller Market Based Rate Authority must be
listed.
Unique identifier given to each service agreement that can be
used by the filing company to produce the agreement, if requested. The identifier may be the number assigned by FERC
for those service agreements that have been filed and approved
by the Commission, or it may be generated as part of an internal identification system.
Unique reference number assigned by the seller for each transaction.
First date and time the product is sold during the quarter.
Last date and time the product is sold during the quarter.
The time zone in which the sales will be made under the contract.
The registered NERC Balancing Authority (formerly called NERC
Control Area) abbreviation used in OASIS applications.
The specific location at which the product is delivered. If receipt
occurs at a trading hub, a standardized hub name must be
used.
See class name definitions below.
A sale, service or product that is not interruptible for economic reasons.
A sale for which delivery or receipt of the energy may be interrupted for any reason or no reason, without liability on the part
of either the buyer or seller.
Designates a dedicated sale of energy and capacity from one or
more than one specified generation unit(s).
Designates an incremental material change to one or more transactions due to a change in settlement results. ‘‘BA’’ may be
used in a refiling after the next quarter’s filing is due to reflect
the receipt of new information. It may not be used to correct an
inaccurate filing.
To be used only when the other available class names do not
apply.
Power sales transactions with durations of one year or greater are
long-term. Transactions with shorter durations are short-term.
See increment name definitions below.
Terms of the particular sale set for up to 6 consecutive hours (≤ 6
consecutive hours) Includes LMP based sales in ISO/RTO markets.
Terms of the particular sale set for more than 6 and up to 60 consecutive hours (> 6 and ≤ 60 consecutive hours) Includes sales
over a peak or off-peak block during a single day.
Terms of the particular sale set for over 60 consecutive hours and
up to 168 consecutive hours (> 60 and ≤ 168 consecutive
hours). Includes sales for a full week and sales for peak and offpeak blocks over a particular week.
Terms of the particular sale set for set for more than 168 consecutive hours up to, but not including, one year (>168 consecutive
hours and < 1 year). Includes sales for full month or multi-week
sales during a given month.
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
EQR DATA DICTIONARY—Continued
Field
No.
Field
Required
Value
Definition
60 ........
Increment Name ....
............................
Y—Yearly ...............
60 ........
Increment Name ....
............................
61 ........
Increment Peaking
Name.
............................
61 ........
Increment Peaking
Name.
Increment Peaking
Name.
Increment Peaking
Name.
Increment Peaking
Name.
Product Name ........
............................
DN/A—Not Applicable.
See definitions for
increment peaking below.
FP—Full Period .....
Terms of the particular sale set for one year or more (≥ 1 year).
Includes all long-term contracts with defined pricing terms (fixedprice, formula, or index).
To be used only when other available increment names do not
apply.
............................
OP—Off-Peak ........
............................
P—Peak .................
............................
............................
64 ........
Transaction Quantity.
Price .......................
65 ........
Rate Units ..............
............................
66 ........
Total Transmission
Charge.
Total Transaction
Charge.
............................
N/A—Not Applicable.
See Product Names
Table, Appendix
A.
Number with up to
4 decimals.
Number with up to
6 decimals.
See Rate Units
Table, Appendix
F.
Number with up to
2 decimals.
Number with up to
2 decimals.
61 ........
61 ........
61 ........
62 ........
63 ........
67 ........
............................
............................
............................
The product described was sold during Peak and Off-Peak hours.
The product described was sold only during those hours designated as off-peak in the NERC region of the point of delivery.
The product described was sold only during those hours designated as on-peak in the NERC region of the point of delivery.
To be used only when the other available increment peaking
names do not apply.
Description of product being offered.
The quantity of the product in this transaction.
Actual price charged for the product per unit. The price reported
cannot be averaged or otherwise aggregated.
Measure appropriate to the price of the product sold.
Payments received for transmission services when explicitly identified.
Transaction Quantity (Field 63) times Price (Field 64) plus Total
Transmission Charge (Field 66).
EQR DATA DICTIONARY—APPENDIX A. PRODUCT NAMES
Product name
Contract
product
Transaction
product
Definition
BLACK START SERVICE ...........................
Service available after a system-wide blackout where a generator participates in system restoration activities without the
availability of an outside electric supply (Ancillary Service).
Energy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction only).
A quantity of demand that is charged on a $/KW or $/MW basis.
Fixed contractual charges assessed on a per customer basis
that could include billing service.
Charges for facilities or portions of facilities that are constructed
or used for the sole use/benefit of a particular customer.
Contractual provisions to supply energy or capacity to another
entity during critical situations.
A quantity of electricity that is sold or transmitted over a period
of time.
Service provided when a difference occurs between the scheduled and the actual delivery of energy to a load obligation.
Transaction whereby the receiver accepts delivery of energy for
a supplier’s account and returns energy at times, rates, and in
amounts as mutually agreed if the receiver is not an RTO/
ISO.
Charge based on the cost or amount of fuel used for generation.
Services provided for bundled transmission, ancillary services
and energy under contracts effective prior to Order No. 888’s
OATTs.
Contract that provides the terms and conditions for a generator,
distribution system owner, transmission owner, transmission
provider, or transmission system to physically connect to a
transmission system or distribution system.
Agreement to participate and be subject to rules of a system operator.
An agreement that requires a unit to run.
BOOKED OUT POWER ..............................
DIRECT
ASSIGNMENT
FACILITIES
CHARGE.
EMERGENCY ENERGY ..............................
ENERGY ......................................................
ENERGY IMBALANCE ................................
EXCHANGE .................................................
FUEL CHARGE ...........................................
GRANDFATHERED BUNDLED ..................
yshivers on PROD1PC62 with NOTICES
CAPACITY ...................................................
CUSTOMER CHARGE ................................
INTERCONNECTION AGREEMENT ..........
MEMBERSHIP AGREEMENT .....................
MUST RUN AGREEMENT ..........................
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1885
EQR DATA DICTIONARY—APPENDIX A. PRODUCT NAMES—Continued
Product name
Contract
product
Transaction
product
Definition
NEGOTIATED-RATE TRANSMISSION ......
NETWORK ...................................................
NETWORK OPERATING AGREEMENT ....
OTHER .........................................................
POINT-TO-POINT AGREEMENT ................
REACTIVE SUPPLY & VOLTAGE CONTROL.
REAL POWER TRANSMISSION LOSS ......
REGULATION
SPONSE.
RE-
REQUIREMENTS SERVICE .......................
SCHEDULE SYSTEM CONTROL & DISPATCH.
SPINNING RESERVE .................................
SUPPLEMENTAL RESERVE ......................
SYSTEM OPERATING AGREEMENTS ......
TOLLING ENERGY .....................................
TRANSMISSION OWNERS AGREEMENT
UPLIFT .........................................................
Transmission performed under a negotiated rate contract (applies only to merchant transmission companies).
Transmission service under contract providing network service.
An executed agreement that contains the terms and conditions
under which a network customer operates its facilities and the
technical and operational matters associated with the implementation of network integration transmission service.
Product name not otherwise included.
Transmission service under contract between specified Points of
Receipt and Delivery.
Production or absorption of reactive power to maintain voltage
levels on transmission systems (Ancillary Service).
The loss of energy, resulting from transporting power over a
transmission system.
Service providing for continuous balancing of resources (generation and interchange) with load, and for maintaining scheduled interconnection frequency by committing on-line generation where output is raised or lowered and by other non-generation resources capable of providing this service as necessary to follow the moment-by-moment changes in load (Ancillary Service).
Firm, load-following power supply necessary to serve a specified share of customer’s aggregate load during the term of the
agreement. Requirements service may include some or all of
the energy, capacity and ancillary service products. (If the
components of the requirements service are priced separately, they should be reported separately in the transactions
tab.)
Scheduling, confirming and implementing an interchange schedule with other Balancing Authorities, including intermediary
Balancing Authorities providing transmission service, and ensuring operational security during the interchange transaction
(Ancillary Service).
Unloaded synchronized generating capacity that is immediately
responsive to system frequency and that is capable of being
loaded in a short time period or non-generation resources capable of providing this service (Ancillary Service).
Service needed to serve load in the event of a system contingency, available with greater delay than SPINNING RESERVE. This service may be provided by generating units
that are on-line but unloaded, by quick-start generation, or by
interruptible load or other non-generation resources capable
of providing this service (Ancillary Service).
An executed agreement that contains the terms and conditions
under which a system or network customer shall operate its
facilities and the technical and operational matters associated
with the implementation of network.
Energy sold from a plant whereby the buyer provides fuel to a
generator (seller) and receives power in return for pre-established fees.
The agreement that establishes the terms and conditions under
which a transmission owner transfers operational control over
designated transmission facilities.
A make-whole payment by an RTO/ISO to a utility.
&
FREQUENCY
EQR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY
yshivers on PROD1PC62 with NOTICES
Balancing authority
Abbreviation
AESC, LLC—Wheatland CIN ....................................................................................................................................
Alabama Electric Cooperative, Inc ............................................................................................................................
Alberta Electric System Operator ..............................................................................................................................
Alliant Energy Corporate Services, LLC—East ........................................................................................................
Alliant Energy Corporate Services, LLC—West .......................................................................................................
Ameren Transmission ...............................................................................................................................................
Ameren Transmission. Illinois ...................................................................................................................................
Ameren Transmission. Missouri ................................................................................................................................
American Transmission Systems, Inc .......................................................................................................................
Aquila Networks—Kansas .........................................................................................................................................
Aquila Networks—Missouri Public Service ...............................................................................................................
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10JAN1
AEWC
AEC
AESO
ALTE
ALTW
AMRN
AMIL
AMMO
FE
WPEK
MPS
Outside US *
........................
........................
........................
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1886
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
EQR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued
yshivers on PROD1PC62 with NOTICES
Balancing authority
Abbreviation
Aquila Networks—West Plains Dispatch ..................................................................................................................
Arizona Public Service Company ..............................................................................................................................
Associated Electric Cooperative, Inc ........................................................................................................................
Avista Corp ................................................................................................................................................................
Batesville Balancing Authority ...................................................................................................................................
Big Rivers Electric Corp ............................................................................................................................................
Board of Public Utilities .............................................................................................................................................
Bonneville Power Administration Transmission ........................................................................................................
British Columbia Transmission Corporation ..............................................................................................................
California Independent System Operator ..................................................................................................................
Carolina Power & Light Company—CPLW ...............................................................................................................
Carolina Power and Light Company—East ..............................................................................................................
Central and Southwest ..............................................................................................................................................
Central Illinois Light Co .............................................................................................................................................
Chelan County PUD ..................................................................................................................................................
Cinergy Corporation ..................................................................................................................................................
City of Homestead ....................................................................................................................................................
City of Independence P&L Dept ...............................................................................................................................
City of Tallahassee ...................................................................................................................................................
City Water Light & Power ..........................................................................................................................................
Cleco Power LLC ......................................................................................................................................................
Columbia Water & Light ............................................................................................................................................
Comision Federal de Electricidad .............................................................................................................................
Constellation Energy Control and Dispatch—Arkansas ...........................................................................................
Constellation Energy Control and Dispatch—City of Benton, AR ............................................................................
Constellation Energy Control and Dispatch—City of Ruston, LA .............................................................................
Constellation Energy Control and Dispatch—Conway, Arkansas ............................................................................
Constellation Energy Control and Dispatch—Gila River ..........................................................................................
Constellation Energy Control and Dispatch—Harquehala ........................................................................................
Constellation Energy Control and Dispatch—North Little Rock, AR ........................................................................
Constellation Energy Control and Dispatch—West Memphis, Arkansas .................................................................
Dairyland Power Cooperative ...................................................................................................................................
DECA, LLC—Arlington Valley ...................................................................................................................................
Duke Energy Corporation ..........................................................................................................................................
East Kentucky Power Cooperative, Inc ....................................................................................................................
El Paso Electric .........................................................................................................................................................
Electric Energy, Inc ...................................................................................................................................................
Empire District Electric Co., The ...............................................................................................................................
Entergy ......................................................................................................................................................................
ERCOT ISO ..............................................................................................................................................................
Florida Municipal Power Pool ...................................................................................................................................
Florida Power & Light ...............................................................................................................................................
Florida Power Corporation ........................................................................................................................................
Gainesville Regional Utilities .....................................................................................................................................
Georgia System Operations Corporation ..................................................................................................................
Georgia Transmission Corporation ...........................................................................................................................
Grand River Dam Authority .......................................................................................................................................
Grant County PUD No. 2 ..........................................................................................................................................
Great River Energy ...................................................................................................................................................
Great River Energy ...................................................................................................................................................
Great River Energy ...................................................................................................................................................
Great River Energy ...................................................................................................................................................
GridAmerica ..............................................................................................................................................................
Hoosier Energy .........................................................................................................................................................
Hydro-Quebec, TransEnergie ...................................................................................................................................
Idaho Power Company .............................................................................................................................................
Illinois Power Co .......................................................................................................................................................
Illinois Power Co .......................................................................................................................................................
Imperial Irrigation District ..........................................................................................................................................
Indianapolis Power & Light Company .......................................................................................................................
ISO New England Inc ...............................................................................................................................................
JEA ............................................................................................................................................................................
Kansas City Power & Light, Co ................................................................................................................................
Lafayette Utilities System ..........................................................................................................................................
LG&E Energy Transmission Services .......................................................................................................................
Lincoln Electric System .............................................................................................................................................
Los Angeles Department of Water and Power .........................................................................................................
Louisiana Energy & Power Authority ........................................................................................................................
Louisiana Generating, LLC .......................................................................................................................................
Madison Gas and Electric Company ........................................................................................................................
Manitoba Hydro Electric Board, Transmission Services ...........................................................................................
Michigan Electric Coordinated System .....................................................................................................................
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10JAN1
WPEC
AZPS
AECI
AVA
BBA
BREC
KACY
BPAT
BCTC
CISO
CPLW
CPLE
CSWS
CILC
CHPD
CIN
HST
INDN
TAL
CWLP
CLEC
CWLD
CFE
PUPP
BUBA
DERS
CNWY
GRMA
HGMA
DENL
WMUC
DPC
DEAA
DUK
EKPC
EPE
EEI
EDE
EES
ERCO
FMPP
FPL
FPC
GVL
GSOC
GTC
GRDA
GCPD
GRE
GREC
GREN
GRES
GA
HE
HQT
IPCO
IP
IPRV
IID
IPL
ISNE
JEA
KCPL
LAFA
LGEE
LES
LDWP
LEPA
LAGN
MGE
MHEB
MECS
Outside US *
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
1887
EQR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued
yshivers on PROD1PC62 with NOTICES
Balancing authority
Abbreviation
Michigan Electric Coordinated System—CONS .......................................................................................................
Michigan Electric Coordinated System—DECO .......................................................................................................
MidAmerican Energy Company ................................................................................................................................
Midwest ISO ..............................................................................................................................................................
Minnesota Power, Inc ...............................................................................................................................................
Montana-Dakota Utilities Co .....................................................................................................................................
Muscatine Power and Water .....................................................................................................................................
Nebraska Public Power District .................................................................................................................................
Nevada Power Company ..........................................................................................................................................
New Brunswick Power Corporation ..........................................................................................................................
New Horizons Electric Cooperative ..........................................................................................................................
New York Independent System Operator .................................................................................................................
North American Electric Reliability Council ...............................................................................................................
Northern Indiana Public Service Company ...............................................................................................................
Northern States Power Company .............................................................................................................................
NorthWestern Energy ................................................................................................................................................
Ohio Valley Electric Corporation ...............................................................................................................................
Oklahoma Gas and Electric ......................................................................................................................................
Ontario—Independent Electricity Market Operator ...................................................................................................
OPPD CA/TP ............................................................................................................................................................
Otter Tail Power Company ........................................................................................................................................
P.U.D. No. 1 of Douglas County ...............................................................................................................................
PacifiCorp-East .........................................................................................................................................................
PacifiCorp-West ........................................................................................................................................................
PJM Interconnection .................................................................................................................................................
Portland General Electric ..........................................................................................................................................
Public Service Company of Colorado .......................................................................................................................
Public Service Company of New Mexico ..................................................................................................................
Puget Sound Energy Transmission ..........................................................................................................................
Reedy Creek Improvement District ...........................................................................................................................
Sacramento Municipal Utility District .........................................................................................................................
Salt River Project ......................................................................................................................................................
Santee Cooper ..........................................................................................................................................................
SaskPower Grid Control Centre ................................................................................................................................
Seattle City Light .......................................................................................................................................................
Seminole Electric Cooperative ..................................................................................................................................
Sierra Pacific Power Co.—Transmission ..................................................................................................................
South Carolina Electric & Gas Company ..................................................................................................................
South Mississippi Electric Power Association ...........................................................................................................
South Mississippi Electric Power Association ...........................................................................................................
Southeastern Power Administration—Hartwell .........................................................................................................
Southeastern Power Administration—Russell ..........................................................................................................
Southeastern Power Administration—Thurmond ......................................................................................................
Southern Company Services, Inc .............................................................................................................................
Southern Illinois Power Cooperative .........................................................................................................................
Southern Indiana Gas & Electric Co .........................................................................................................................
Southern Minnesota Municipal Power Agency .........................................................................................................
Southwest Power Pool ..............................................................................................................................................
Southwestern Power Administration .........................................................................................................................
Southwestern Public Service Company ....................................................................................................................
Sunflower Electric Power Corporation ......................................................................................................................
Tacoma Power ..........................................................................................................................................................
Tampa Electric Company ..........................................................................................................................................
Tennessee Valley Authority ESO ..............................................................................................................................
Trading Hub ..............................................................................................................................................................
TRANSLink Management Company .........................................................................................................................
Tucson Electric Power Company ..............................................................................................................................
Turlock Irrigation District ...........................................................................................................................................
Upper Peninsula Power Co .......................................................................................................................................
Utilities Commission, City of New Smyrna Beach ....................................................................................................
Westar Energy—MoPEP Cities .................................................................................................................................
Western Area Power Administration—Colorado—Missouri ......................................................................................
Western Area Power Administration—Lower Colorado ............................................................................................
Western Area Power Administration—Upper Great Plains East ..............................................................................
Western Area Power Administration—Upper Great Plains West .............................................................................
Western Farmers Electric Cooperative .....................................................................................................................
Western Resources dba Westar Energy ..................................................................................................................
Wisconsin Energy Corporation ..................................................................................................................................
Wisconsin Public Service Corporation ......................................................................................................................
Yadkin, Inc ................................................................................................................................................................
CONS
DECO
MEC
MISO
MP
MDU
MPW
NPPD
NEVP
NBPC
NHC1
NYIS
TEST
NIPS
NSP
NWMT
OVEC
OKGE
IMO
OPPD
OTP
DOPD
PACE
PACW
PJM
PGE
PSCO
PNM
PSEI
RC
SMUD
SRP
SC
SPC
SCL
SEC
SPPC
SCEG
SME
SMEE
SEHA
SERU
SETH
SOCO
SIPC
SIGE
SMP
SWPP
SPA
SPS
SECI
TPWR
TEC
TVA
HUB
TLKN
TEPC
TIDC
UPPC
NSB
MOWR
WACM
WALC
WAUE
WAUW
WFEC
WR
WEC
WPS
YAD
Outside US *
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* Balancing authorities outside the United States may only be used in the Contract Data section to identify specified receipt/delivery points in
jurisdictional transmission contracts.
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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
EQR DATA DICTIONARY—APPENDIX C. HUB
HUB
Definition
ADHUB ...........................
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the AEP/Dayton
Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the AEPGenHub.
The set of delivery points along the California-Oregon border commonly identified as and agreed to by the
counterparties to constitute the COB Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the
Cinergy balancing authority.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as Cinergy Hub (MISO).
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the
Entergy balancing authority.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as FE Hub (MISO).
The set of delivery points at the Four Corners power plant commonly identified as and agreed to by the
counterparties to constitute the Four Corners Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as Illinois Hub (MISO).
The set of delivery points at or near Hoover Dam commonly identified as and agreed to by the counterparties to constitute the Mead Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as Michigan Hub (MISO).
The set of delivery points along the Columbia River commonly identified as and agreed to by the counterparties to
constitute the Mid-Columbia Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as Minnesota Hub (MISO).
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by ISO New England Inc., as Mass Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the Northern Illinois Hub.
The set of delivery points along the Nevada-Oregon border commonly identified as and agreed to by the
counterparties to constitute the NOB Hub.
The set of delivery points north of Path 15 on the California transmission grid commonly identified as and agreed to
by the counterparties to constitute the NP15 Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the
Northwestern Energy Montana balancing authority.
The aggregated Locational Marginal Price nodes (‘‘LMP’’) defined by PJM Interconnection, LLC as the PJM East
Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the PJM South
Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the PJM Western
Hub.
The switch yard at the Palo Verde nuclear power station west of Phoenix in Arizona. Palo Verde Hub includes the
Hassayampa switchyard 2 miles south of Palo Verde.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the
Southern Company balancing authority.
The set of delivery points south of Path 15 on the California transmission grid commonly identified as and agreed to
by the counterparties to constitute the SP15 Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the
Tennessee Valley Authority balancing authority.
The set of delivery points associated with Path 26 on the California transmission grid commonly identified as and
agreed to by the counterparties to constitute the ZP26 Hub.
AEPGenHub ...................
COB ................................
Cinergy (into) ..................
Cinergy Hub (MISO) .......
Entergy (into) ..................
FE Hub ............................
Four Corners ...................
Illinois Hub (MISO) .........
Mead ...............................
Michigan Hub (MISO) .....
Mid-Columbia (Mid-C) .....
Minnesota Hub (MISO) ...
NEPOOL (Mass Hub) .....
NIHUB .............................
NOB ................................
NP15 ...............................
NWMT .............................
PJM East Hub .................
PJM South Hub ..............
PJM West Hub ................
Palo Verde ......................
SOCO (into) ....................
SP15 ...............................
TVA (into) ........................
ZP26 ...............................
EQR DATA DICTIONARY—APPENDIX D.
TIME ZONE
yshivers on PROD1PC62 with NOTICES
Time zone
AD
AP
AS
CD
CP
CS
ED
EP
ES
MD
MP
MS
NA
PD
Definition
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VerDate Aug<31>2005
EQR DATA DICTIONARY—APPENDIX D.
TIME ZONE—Continued
Atlantic Daylight.
Atlantic Prevailing.
Atlantic Standard.
Central Daylight.
Central Prevailing.
Central Standard.
Eastern Daylight.
Eastern Prevailing.
Eastern Standard.
Mountain Daylight.
Mountain Prevailing.
Mountain Standard.
Not Applicable.
Pacific Daylight.
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Time zone
Definition
PP ........................
PS ........................
UT ........................
Pacific Prevailing.
Pacific Standard.
Universal Time.
EQR DATA DICTIONARY—APPENDIX E.
UNITS
Units
KV ...............
KVA ............
KVR ............
KW ..............
PO 00000
Frm 00027
Definition
Kilovolt.
Kilovolt Amperes.
Kilovar.
Kilowatt.
Fmt 4703
Sfmt 4703
EQR DATA DICTIONARY—APPENDIX E.
UNITS—Continued
Units
KWH ...........
KW–DAY ....
KW–MO ......
KW–WK ......
KW–YR .......
MVAR–YR ..
MW .............
MWH ..........
MW–DAY ....
MW–MO .....
MW–WK .....
MW–YR ......
RKVA ..........
FLAT RATE
E:\FR\FM\10JAN1.SGM
10JAN1
Definition
Kilowatt Hour.
Kilowatt Day.
Kilowatt Month.
Kilowatt Week.
Kilowatt Year.
Megavar Year.
Megawatt.
Megawatt Hour.
Megawatt Day.
Megawatt Month.
Megawatt Week.
Megawatt Year.
Reactive Kilovolt Amperes.
Flat Rate.
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices
EQR DATA DICTIONARY—APPENDIX F.
RATE UNITS
Rate units
Definition
$/KV ..................
$/KVA ...............
$/KVR ...............
$/KW .................
$/KWH ..............
$/KW–DAY .......
$/KW–MO .........
$/KW–WK .........
$/KW–YR ..........
$/MW ................
$/MWH ..............
$/MW–DAY .......
$/MW–MO ........
$/MW–WK ........
$/MW–YR .........
$/MVAR–YR .....
$/RKVA .............
CENTS .............
CENTS/KVR .....
CENTS/KWH ....
FLAT RATE ......
dollars per kilovolt.
dollars per kilovolt amperes.
dollars per kilovar.
dollars per kilowatt.
dollars per kilowatt hour.
dollars per kilowatt day.
dollars per kilowatt month.
dollars per kilowatt week.
dollars per kilowatt year.
dollars per megawatt.
dollars per megawatt hour.
dollars per megawatt day.
dollars per megawatt
month.
dollars per megawatt
week.
dollars per megawatt year.
dollars per megavar year.
dollars per reactive kilovar
amperes.
cents.
cents per kilovolt amperes.
cents per kilowatt hour.
rate not specified in any
other units.
[FR Doc. E8–184 Filed 1–9–08; 8:45 am]
BILLING CODE 6717–01–P
FEDERAL HOUSING FINANCE BOARD
Sunshine Act Meeting Notice;
Announcing a Partially Open Meeting
of the Board of Directors
The open meeting of the
Board of Directors is scheduled to begin
at 10 am on Tuesday, January 15, 2008.
The closed portion of the meeting will
follow immediately the open portion of
the meeting.
PLACE: Board Room, First Floor, Federal
Housing Finance Board, 1625 Eye
Street, NW., Washington, DC 20006.
STATUS: The first portion of the meeting
will be open to the public. The final
portion of the meeting will be closed to
the public.
TIME AND DATE:
MATTER TO BE CONSIDERED AT THE OPEN
PORTION: Federal Home Loan Bank of
San Francisco—Waiver of Certain AHP
Regulations to Permit Refinancing/
Modification of Subprime Mortgage
Loans.
yshivers on PROD1PC62 with NOTICES
MATTER TO BE CONSIDERED AT THE CLOSED
PORTION: Periodic Update of
Examination Program Development and
Supervisory Findings.
CONTACT PERSON FOR MORE INFORMATION:
Shelia Willis, Paralegal Specialist,
Office of General Counsel, at 202–408–
2876 or williss@fhfb.gov.
Dated: January 8, 2008.
VerDate Aug<31>2005
14:29 Jan 09, 2008
Jkt 214001
By the Federal Housing Finance Board.
Neil R. Crowley,
Acting General Counsel.
[FR Doc. 08–85 Filed 1–8–08; 3:59 pm]
BILLING CODE 6725–01–P
FEDERAL RESERVE SYSTEM
1889
applied to become a bank holding
company by merging with NKC
Bancshares Inc.
Board of Governors of the Federal Reserve
System, January 7, 2008.
Robert deV. Frierson,
Deputy Secretary of the Board.
[FR Doc. E8–262 Filed 1–9–08; 8:45 am]
Formations of, Acquisitions by, and
Mergers of Bank Holding Companies
BILLING CODE 6210–01–S
The companies listed in this notice
have applied to the Board for approval,
pursuant to the Bank Holding Company
Act of 1956 (12 U.S.C. 1841 et seq.)
(BHC Act), Regulation Y (12 CFR Part
225), and all other applicable statutes
and regulations to become a bank
holding company and/or to acquire the
assets or the ownership of, control of, or
the power to vote shares of a bank or
bank holding company and all of the
banks and nonbanking companies
owned by the bank holding company,
including the companies listed below.
The applications listed below, as well
as other related filings required by the
Board, are available for immediate
inspection at the Federal Reserve Bank
indicated. The application also will be
available for inspection at the offices of
the Board of Governors. Interested
persons may express their views in
writing on the standards enumerated in
the BHC Act (12 U.S.C. 1842(c)). If the
proposal also involves the acquisition of
a nonbanking company, the review also
includes whether the acquisition of the
nonbanking company complies with the
standards in section 4 of the BHC Act
(12 U.S.C. 1843). Unless otherwise
noted, nonbanking activities will be
conducted throughout the United States.
Additional information on all bank
holding companies may be obtained
from the National Information Center
Web site at www.ffiec.gov/nic/.
Unless otherwise noted, comments
regarding each of these applications
must be received at the Reserve Bank
indicated or the offices of the Board of
Governors not later than February 5,
2008.
A. Federal Reserve Bank of Kansas
City (Todd Offerbacker, Assistant Vice
President) 925 Grand Avenue, Kansas
City, Missouri 64198–0001:
1. Young Partners, L.P., and its
general partner, Young Corporation,
and Citizens Bancshares Company, all
of Chillicothe, Missouri, and First
Community Bancshares, Inc., and FCB
Acquisition Corp., both of Overland
Park, Kansas; to acquire NKC
Bancshares, Inc., and thereby indirectly
acquire Norbank, both of North Kansas
City, Missouri. In connection with this
application, FCB Acquisition Corp, has
DEPARTMENT OF HEALTH AND
HUMAN SERVICES
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Centers for Disease Control and
Prevention
[60Day–08–0008]
Proposed Data Collections Submitted
for Public Comment and
Recommendations
In compliance with the requirement
of section 3506(c)(2)(A) of the
Paperwork Reduction Act of 1995 for
opportunity for public comment on
proposed data collection projects, the
Centers for Disease Control and
Prevention (CDC) will publish periodic
summaries of proposed projects. To
request more information on the
proposed projects or to obtain a copy of
the data collection plans and
instruments, call 404–639–5960 and
send comments to Maryam I. Daneshvar,
CDC Acting Reports Clearance Officer,
1600 Clifton Road, MS–D74, Atlanta,
GA 30333 or send an e-mail to
omb@cdc.gov.
Comments are invited on: (a) Whether
the proposed collection of information
is necessary for the proper performance
of the functions of the agency, including
whether the information shall have
practical utility; (b) the accuracy of the
agency’s estimate of the burden of the
proposed collection of information; (c)
ways to enhance the quality, utility, and
clarity of the information to be
collected; and (d) ways to minimize the
burden of the collection of information
on respondents, including through the
use of automated collection techniques
or other forms of information
technology. Written comments should
be received within 60 days of this
notice.
Proposed Project
Hazardous Substances Emergency
Events Surveillance (HSEES)—
Extension—(0923–0008), Agency for
Toxic Substances and Disease Registry
(ATSDR), Centers for Disease Control
and Prevention (CDC).
Background and Brief Description
The Agency for Toxic Substances and
Disease Registry (ATSDR) is mandated
E:\FR\FM\10JAN1.SGM
10JAN1
]]>Agencies
[Federal Register Volume 73, Number 7 (Thursday, January 10, 2008)]
[Notices]
[Pages 1876-1889]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E8-184]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
[Docket No. RM01-8-007]
Revised Public Utility Filing Requirements for Electric Quarterly
Reports
December 21, 2007.
AGENCY: Federal Energy Regulatory Commission, Department of Energy.
ACTION: Order No. 2001-H; Order on Rehearing and Clarification.
-----------------------------------------------------------------------
SUMMARY: In this order, the Federal Energy Regulatory Commission
(Commission) grants in part, and denies in part, rehearing and
clarifies the information to be reported in the Electric Quarterly
Report's (EQR'S) fields for Contract Execution Date (Field No. 21),
Contract Commencement Date (Field No. 22) and Rate Description (Field
No. 37). In addition, the order corrects an error relating to Increment
Name (Field Nos. 28 and 60).
DATES: This order becomes effective upon issuance. The revised
definitions adopted in this order shall be applied to EQR filings
beginning with the Q1 2008 EQR (due on April 30, 2008) and in
subsequent EQR filings due thereafter.
FOR FURTHER INFORMATION CONTACT:
Michelle Veloso (Technical Information), Office of Enforcement,
Federal Energy Regulatory Commission, 888 First Street, NE.,
Washington, DC 20426, (202) 502-8363.
Gary D. Cohen (Legal Information), Office of the General Counsel,
Federal Energy Regulatory Commission, 888
[[Page 1877]]
First Street, NE., Washington, DC 20426, (202) 502-8321.
SUPPLEMENTARY INFORMATION:
Before Commissioners: Joseph T. Kelliher, Chairman; Suedeen G.
Kelly, Marc Spitzer, Philip D. Moeller, and Jon Wellinghoff.
1. On October 24, 2007, Edison Electric Institute (EEI) filed a
request for rehearing or clarification in response to the Commission's
order adopting an Electric Quarterly Report (EQR) Data Dictionary.\1\
Order No. 2001-G collected in one document the definitions of certain
terms and values used in filing EQR data (previously provided in
Commission orders and in guidance materials posted at the Commission's
website) and issued formal definitions for fields that were previously
undefined.\2\ In this order, the Commission grants in part, and denies
in part, rehearing and clarifies the information to be reported in
Contract Execution Date (Field No. 21), Contract Commencement Date
(Field No. 22) and Rate Description (Field No. 37). In addition, we
correct an error that we made in Order No. 2001-G relating to Increment
Name (Field Nos. 28 and 60).
---------------------------------------------------------------------------
\1\ Revised Public Utility Filing Requirements for Electric
Quarterly Reports, Order No. 2001-G, 120 FERC ] 61,270 (Sep. 24,
2007), 72 FR 56735 (Oct. 4, 2007).
\2\ Id.
---------------------------------------------------------------------------
I. Background
2. On April 25, 2002, the Commission issued Order No. 2001, a Final
Rule establishing revised public utility filing requirements.\3\ This
rule revised the Commission's filing requirements to require companies
subject to the Commission's regulations under section 205 of the
Federal Power Act to file quarterly reports that: (1) Provide data
identifying the utility on whose behalf the report is being filed (ID
Data); (2) summarize pertinent data about the utility's currently
effective contracts (Contract Data); and (3) summarize data about
wholesale power sales the utility made during the reporting period
(Transaction Data). The requirement to file EQRs replaced the
requirement to file quarterly transaction reports summarizing a
utility's market-based rate transactions and sales agreements that
conformed to the utility's tariff.
---------------------------------------------------------------------------
\3\ Revised Public Utility Filing Requirements for, Order No.
2001, 67 FR 31043, FERC Stats. & Regs. ] 31,127 (2002), reh'g
denied, Order No. 2001-A, 100 FERC ] 61,074, reconsideration and
clarification denied, Order No. 2001-B, 100 FERC ] 61,342, order
directing filings, Order No. 2001-C, 101 FERC ] 61,314 (2002), order
directing filings, Order No. 2001-D, 102 FERC ( 61,334, order
refining filing requirements, Order No. 2001-E, 105 FERC ] 61,352
(2003), clarification order, Order No. 2001-F, 106 FERC ] 61,060
(2004).
---------------------------------------------------------------------------
3. In Order No. 2001, the Commission also adopted a new section in
its regulations, 18 CFR 35.10b, which requires that the EQRs are to be
prepared in conformance with the Commission's software and guidance
posted and available from the Commission website. This obviates the
need to revise section 35.10b to implement revisions to the software
and guidance. Since the issuance of Order No. 2001, as need has arisen,
the Commission has issued orders to resolve questions raised by EQR
users and has directed Staff to issue additional guidance.\4\
---------------------------------------------------------------------------
\4\ Examples cited in EQR Notice at P 3.
---------------------------------------------------------------------------
4. On September 24, 2007, the Commission issued Order No. 2001-G,
providing a data dictionary to clarify the information to be reported
in EQR data. EEI filed a request for rehearing or clarification
requesting clarification of a few specific items. In addition, on
December 4, 2007, TransAlta filed comments alerting the Commission to a
filing problem it was experiencing relating to Increment Name (Field
Nos. 28 and 60). The discussion below addresses EEI's rehearing request
and TransAlta's comments.
II. Discussion
A. Field No. 21--Contract Execution Date
5. The EQR Notice \5\ proposed only a slight change to the Order
No. 2001 definition for Contract Execution Date: ``The date the
contract was signed. If the parties signed on different dates, or there
are contract amendments, use the most recent date signed.''
---------------------------------------------------------------------------
\5\ Notice Seeking Comments on Proposed Electric Quarterly
Report Data Dictionary, FERC Stats. & Regs. ] 35,050 (2007), 72 FR
26091 (May 8, 2007).
---------------------------------------------------------------------------
6. In response to the EQR Notice, Reliant and EEI suggested that
the Contract Execution Date should not change because of a minor
amendment to the contract. Both commenters noted that, frequently,
contract amendments are minor changes, such as changes in an address or
in payment terms, that do not affect the key operational parameters of
the agreement.
7. Based on these comments, the Commission found in Order No. 2001-
G that the usefulness of the data may be increased with a single
execution date for each contract across all periods. However, the order
explained that, if there are material amendments to the contract, then
the Contract Execution Date must be changed.
8. In EEI's request for rehearing, it argues that the Commission's
instruction that the Contract Execution Date must be changed when there
are material amendments to the contract is confusing and burdensome. It
suggests that the original execution date should be reported for the
duration of the contract and argues that changes in the contract will
be reflected in the descriptions of revised contract provisions, such
as in the Rate (Field No. 34), Begin Date (Field No. 43) and End Date
fields (Field No. 44).
Commission Conclusion
9. In Order No. 2001-G, the Commission agreed with EEI and Reliant
that it need not change the Contract Execution Date each time there is
a minor revision to the contract and, accordingly, modified the
instructions on what information should be reported in this field. The
Commission reduced the burden and confusion by clarifying that minor,
non-material changes may be omitted for the purpose of identifying the
Contract Execution Date. EEI argues that the Contract Execution Date
should not be revised, even in instances where there has been a
material amendment to the contract.
10. The Commission recognizes the benefits of classifying a
contractual relationship based on when it originated and will revise
the definition of Contract Execution Date as EEI suggests to require
companies to report the original date the contract was executed,
without regard to any subsequent revisions to the contract. For the
purposes of the EQR Data Dictionary, the definition will read: ``The
date the contract was signed. If the parties signed on different dates,
use the most recent date signed.'' However, this change will not be
incorporated at the cost of obscuring information that would alert EQR
users that key terms in the contract have been revised. Thus, the
Commission will revise the definition of Contract Commencement Date as
described below.
B. Field No. 22--Contract Commencement Date
11. In order to alert EQR users that a contract has been revised,
the Commission will revise the definition of Contract Commencement Date
to refer to the date that service commenced under the current terms and
conditions of the contract. The Commission will further clarify that
the terms deemed relevant for determining or changing the Contract
Commencement Date are those that are reported in the Contract Data
section of the EQR.\6\ Any amendment
[[Page 1878]]
that would cause a change in these required data elements would require
a change in the Contract Commencement Date.
---------------------------------------------------------------------------
\6\ In developing the EQR, the Commission identified a number of
key terms associated with the products and services offered under
any given jurisdictional contract. These terms include: Class Name,
Term Name, Increment Name, Increment Peaking Name, Increment Peaking
Name, Product Type Name, Product Name, Rate (actual, maximum,
minimum or description), and Time Zone. The Commission requires that
Class Name, Term Name, Increment Name, Increment Peaking Name,
Product Type Name, Product Name, and Time Zone be reported in the
EQR for every product offered under every jurisdictional contract.
Additionally, the Commission requires a definition of the rate for
every product either as a Rate, a Rate Minimum, a Rate Maximum or a
Rate Description. Finally, the Commission requires that companies
report, when specified in the contract for a given product,
Quantity, Units, Rate Units, Point of Receipt Control Area, Point of
Receipt Specific Location, Point of Delivery Control Area, Point of
Delivery Specific Location, Begin Date, and End Date.
---------------------------------------------------------------------------
12. The Commission recognizes EEI's concern regarding potential
inconsistency between the EQR and eTariff in identifying an original
execution date. However, there is a very real public interest in
identifying when key terms of the contract were determined. As market
conditions change over time, it is imperative to be able to sort the
deals that occurred years ago from those that were confirmed more
recently. To better understand the market conditions at the time a
contract was put in place, it is necessary to document the date that
key terms were established.
13. The Commission will define Contract Commencement Date as ``The
date the terms of the contract reported in the EQR were effective. If
the terms reported in the Contract Data section of the EQR became
effective or if service under those terms began on multiple dates
(i.e.: due to an amendment), the date to be reported as the
Commencement Date is the date when service began pursuant to the most
recent amendment to the terms reported in the Contract Data section of
the EQR.'' In this way, the Commission and the public will continue to
be able to determine when the contract terms reported in the EQR were
determined.
C. Field Nos. 28 and 60--Increment Name
14. In the EQR Notice,\7\ the Commission proposed to revise Field
Nos. 28 and 60 to, among other matters, create an Increment Name
covering ``Seasonal'' sales to characterize power sales made for longer
than one month, but less than a year.\8\ This proposal was opposed in
comments filed by EEI, Reliant and Occidental. In Order No. 2001-G, the
Commission agreed with the commenters that the term ``S--Seasonal''
should not be included in the options available for the Increment Name
fields. However, in the issued Order No. 2001-G, when the term
``Seasonal'' was dropped from the Data Dictionary, the interval to be
included in ``Monthly'' should have been adjusted in the attached Data
Dictionary, so there would be no gap between ``Monthly'' and
``Annual.'' Unfortunately, this correction was inadvertently omitted.
---------------------------------------------------------------------------
\7\ Revised Public Utility Filing Requirements for Electric
Quarterly Reports, 72 Fed. Reg. 26091 (May 8, 2007), FERC Stats. &
Regs. ] 35,050 (2007) (EQR Notice).
\8\ EQR Notice at P. 18.
---------------------------------------------------------------------------
15. On December 4, 2007, TransAlta filed comments alerting the
Commission to this problem.
Commission Conclusion
16. We will take this opportunity to correct the inadvertent error
in Order No. 2001-G involving Increment Name, so that filers can
accurately report their sales covering a period of more than 168
consecutive hours up to one year as M-Monthly (>168 consecutive hours
and < 1 year).
D. Field No. 37--Rate Description
17. The EQR Notice proposed defining Rate Description as a ``[t]ext
description of rate. May reference FERC tariff, or, if a discounted or
negotiated rate, include algorithm.'' EEI filed comments in response to
the EQR Notice requesting that filers be allowed to enter the tariff
location into the Rate Description field in lieu of a detailed
description of the rate itself. EEI supported this request by citing
the difficulty of putting complex rates into the 150 character field.
In Order No. 2001-G, the Commission stated that the EQR fulfills the
Commission's statutory obligation under the Federal Power Act (FPA) to
have companies' rates on file. We further stated that the Commission
relies on the EQR to satisfy the FPA requirement that rates provided in
a contract be publicly disclosed and on file. Thus, we concluded that
it is imperative that the information reported in EQRs provide an
adequate level of detail and transparency.
18. The Commission also stated in Order No. 2001-G that a tariff
reference alone, instead of the actual rate description, does not meet
the FPA standard. Allowing filers to substitute a tariff reference in
place of an actual rate description would force EQR users seeking this
information to conduct further research to track down the contents of
the tariff on file. This is clearly less transparent than a rate
description that actually describes the rate. We also explained that,
if the tariff reference is coupled with a descriptive summary of the
rate, where the rate is the function of a complex algorithm, the
standard is met. Further, we explained that rate information will
continue to be available to the public at a level sufficient to explain
the bases and methods of calculation with additional detail available
upon request to interested persons.
19. On rehearing, EEI argues that, in the case of cost-based rates,
the FPA requirement that rates be on file is satisfied by separate on-
the-record Commission filings, so it is not necessary to provide a rate
description in the EQR to satisfy the FPA. Thus, it argues, a reference
to the rate schedule number and page is sufficient for EQR purposes,
without any text description of the rate.
Commission Conclusion
20. Prior to the adoption of Order No. 2001, public utilities
satisfied the FPA requirement to have their rates on file with the
Commission without filing EQRs (which had not yet been established).
Thus, EEI is correct that the EQR filings are not the sole means by
which this legal requirement can be met. However, section 205(c)
provides the Commission with wide discretion on how companies are to
file their rates and, in Order No. 2001, the Commission established the
EQR as a means to ensure compliance with the FPA, and to provide a
mechanism for the public to inspect and review the pertinent terms and
conditions of public utilities' contracts and transactions in an
electronic format that afforded greater transparency and accessibility
to this information.\9\
---------------------------------------------------------------------------
\9\ See, for example, Order No. 2001 at P. 95.
---------------------------------------------------------------------------
21. When this issue first was considered in Order No. 2001-G, it
centered on the question of whether 150 characters would be sufficient
to provide all the information needed to accurately describe a public
utility's rates. After consideration of EEI's arguments and the problem
of fitting an accurate rate description into 150 characters without
sacrificing transparency, we are persuaded to revise the definition for
Rate Description to include a provision that relates to a rate that is
currently on file with the Commission. The Commission will define Rate
Description as ``[t]ext description of rate. If the rate is currently
available on the FERC Web site, a citation of the FERC Accession Number
and the relevant FERC tariff including page number or section may be
included instead of providing the entire rate algorithm. If the rate is
not available on the FERC Web site, include the rate algorithm, if rate
is calculated.
[[Page 1879]]
If the algorithm would exceed the 150 character field limit, it may be
provided in a descriptive summary (including bases and methods of
calculations) with a detailed citation of the relevant FERC tariff
including page number and section. If more than 150 characters are
required, the contract product may be repeated in subsequent lines of
data until the rate is adequately described.'' With this revision of
Rate Description, EQR filers may provide the necessary information
without sacrificing transparency.
III. Document Availability
22. In addition to publishing the full text of this document in the
Federal Register, the Commission provides all interested persons an
opportunity to view and/or print the contents of this document via the
Internet through the Commission's Home Page (https://www.ferc.gov) and
in the Commission's Public Reference Room during normal business hours
(8:30 a.m. to 5 p.m. Eastern time) at 888 First Street, NE., Room 2A,
Washington, DC 20426.
23. From the Commission's Home Page on the Internet, this
information is available in the eLibrary. The full text of this
document is available in the eLibrary both in PDF and Microsoft Word
format for viewing, printing, and/or downloading. To access this
document in eLibrary, type ``RM01-8'' in the docket number field. User
assistance is available for eLibrary and the Commission's website
during the Commission's normal business hours. For assistance contact
the Commission's Online Support services at FERCOnlineSupport@ferc.gov
or toll-free at (866) 208-3676, or for TTY, contact (202) 502-8659.
The Commission orders:
(A) EEI's request for rehearing or clarification is hereby granted
in part, and denied in part, as discussed in the body of this order.
(B) TransAlta's request for clarification is hereby granted, as
discussed in the body of this order.
(C) The revised definitions adopted in this order shall be applied
to EQR filings beginning with the Q1 2008 EQR (due on April 30, 2008)
and in subsequent EQR filings due thereafter.
By the Commission.
Kimberly D. Bose,
Secretary.
Attachment
Electric Quarterly Report Data Dictionary Version 1.0 (Issued --)
EQR Data Dictionary
----------------------------------------------------------------------------------------------------------------
Field No. Field Required Value Definition
----------------------------------------------------------------------------------------------------------------
ID Data
----------------------------------------------------------------------------------------------------------------
1.......... Filer Unique [check].......... FR1.............. (Respondent)--An identifier (i.e.,
Identifier. ``FR1'') used to designate a record
containing Respondent identification
information in a comma-delimited (csv)
file that is imported into the EQR
filing. Only one record with the FR1
identifier may be imported into an EQR
for a given quarter.
1.......... Filer Unique [check].......... FS (Seller)--An identifier (e.g., ``FS1'',
Identifier. (where ``'' is an containing Seller identification
integer). information in a comma-delimited (csv)
file that is imported into the EQR
filing. One record for each seller
company may be imported into an EQR for a
given quarter.
1.......... Filer Unique [check].......... FA1.............. (Agent)--An identifier (i.e., ``FA1'')
Identifier. used to designate a record containing
Agent identification information in a
comma-delimited (csv) file that is
imported into the EQR filing. Only one
record with the FA1 identifier may be
imported into an EQR for a given quarter.
2.......... Company Name..... [check].......... Unrestricted text (Respondent)--The name of the company
(100 characters). taking responsibility for complying with
the Commission's regulations related to
the EQR.
2.......... Company Name..... [check].......... Unrestricted text (Seller)--The name of the company that is
(100 characters). authorized to make sales as indicated in
the company's FERC tariff(s). This name
may be the same as the Company Name of
the Respondent.
2.......... Company Name..... [check].......... Unrestricted text (Agent)--The name of the entity completing
(100 characters). the EQR filing. The Agent's Company Name
need not be the name of the company under
Commission jurisdiction.
3.......... Company DUNS for Respondent Nine digit number The unique nine digit number assigned by
Number. and Seller. Dun and Bradstreet to the company
identified in Field Number 2.
4.......... Contact Name..... [check].......... Unrestricted text (Respondent)--Name of the person at the
(50 characters). Respondent's company taking
responsibility for compliance with the
Commission's EQR regulations.
4.......... Contact Name..... [check].......... Unrestricted text (Seller)--The name of the contact for the
(50 characters). company authorized to make sales as
indicated in the company's FERC
tariff(s). This name may be the same as
the Contact Name of the Respondent.
4.......... Contact Name..... [check].......... Unrestricted text (Agent)--Name of the contact for the
(50 characters). Agent, usually the person who prepares
the filing.
5.......... Contact Title.... [check].......... Unrestricted text Title of contact identified in Field
(50 characters). Number 4.
6.......... Contact Address.. [check].......... Unrestricted text Street address for contact identified in
Field Number 4.
7.......... Contact City..... [check].......... Unrestricted text City for the contact identified in Field
(30 characters). Number 4.
8.......... Contact State.... [check].......... Unrestricted text Two character state or province
(2 characters). abbreviations for the contact identified
in Field Number 4.
[[Page 1880]]
9.......... Contact Zip...... [check].......... Unrestricted text Zip code for the contact identified in
(10 characters). Field Number 4.
10......... Contact Country [check].......... CA--Canada....... Country (USA, Canada, Mexico, or United
Name. MX--Mexico....... Kingdom) for contact address identified
US--United States in Field Number 4.
UK--United
Kingdom.
11......... Contact Phone.... [check].......... Unrestricted text Phone number of contact identified in
(20 characters). Field Number 4.
12......... Contact E-Mail... [check].......... Unrestricted text E-mail address of contact identified in
Field Number 4.
13......... Filing Quarter... [check].......... YYYYMM........... A six digit reference number used by the
EQR software to indicate the quarter and
year of the filing for the purpose of
importing data from csv files. The first
4 numbers represent the year (e.g.,
2007). The last 2 numbers represent the
last month of the quarter (e.g., 03 = 1st
quarter; 06 = 2nd quarter, 09 = 3rd
quarter, 12 = 4th quarter).
----------------------------------------------------------------------------------------------------------------
Contract Data
----------------------------------------------------------------------------------------------------------------
14......... Contract Unique [check].......... An integer An identifier beginning with the letter
ID. proceeded by the ``C'' and followed by a number (e.g.,
letter ``C'' ``C1'', ``C2'') used to designate a
(only used when record containing contract information in
importing a comma-delimited (csv) file that is
contract data) imported into the EQR filing. One record
for each contract product may be imported
into an EQR for a given quarter.
15......... Seller Company [check].......... Unrestricted text The name of the company that is authorized
Name. (100 characters). to make sales as indicated in the
company's FERC tariff(s). This name must
match the name provided as a Seller's
``Company Name'' in Field Number 2 of the
ID Data (Seller Data).
16......... Customer Company [check].......... Unrestricted text The name of the counterparty.
Name. (70 characters).
17......... Customer DUNS [check].......... Nine digit number The unique nine digit number assigned by
Number. Dun and Bradstreet to the company
identified in Field Number 16.
18......... Contract [check].......... Y (Yes).......... The customer is an affiliate if it
Affiliate. N (No)........... controls, is controlled by or is under
common control with the seller. This
includes a division that operates as a
functional unit. A customer of a seller
who is an Exempt Wholesale Generator may
be defined as an affiliate under the
Public Utility Holding Company Act and
the FPA.
19......... FERC Tariff [check].......... Unrestricted text The FERC tariff reference cites the
Reference. (60 characters). document that specifies the terms and
conditions under which a Seller is
authorized to make transmission sales,
power sales or sales of related
jurisdictional services at cost-based
rates or at market-based rates. If the
sales are market-based, the tariff that
is specified in the FERC order granting
the Seller Market Based Rate Authority
must be listed.
20......... Contract Service [check].......... Unrestricted text Unique identifier given to each service
Agreement ID. (30 characters). agreement that can be used by the filing
company to produce the agreement, if
requested. The identifier may be the
number assigned by FERC for those service
agreements that have been filed with and
accepted by the Commission, or it may be
generated as part of an internal
identification system.
21......... Contract [check].......... YYYYMMDD......... The date the contract was signed. If the
Execution Date. parties signed on different dates, use
the most recent date signed.
22......... Contract [check].......... YYYYMMDD......... The date the terms of the contract
Commencement reported in the EQR were effective. If
Date. the terms reported in the Contract Data
section of the EQR became effective or if
service under those terms began on
multiple dates (i.e.: due to an
amendment), the date to be reported as
the Commencement Date is the date when
service began pursuant to the most recent
amendment to the terms reported in the
Contract Data section of the EQR.
23......... Contract If specified in YYYYMMDD......... The date that the contract expires.
Termination Date. the contract.
24......... Actual If contract YYYYMMDD......... The date the contract actually terminates.
Termination Date. terminated.
25......... Extension [check].......... Unrestricted text Description of terms that provide for the
Provision continuation of the contract.
Description.
26......... Class Name....... [check].......... ................. See definitions of each class name below.
26......... Class Name....... [check].......... F--Firm.......... For transmission sales, a service or
product that always has priority over non-
firm service. For power sales, a service
or product that is not interruptible for
economic reasons.
[[Page 1881]]
26......... Class Name....... [check].......... NF--Non-firm..... For transmission sales, a service that is
reserved and/or scheduled on an as-
available basis and is subject to
curtailment or interruption at a lesser
priority compared to Firm service. For an
energy sale, a service or product for
which delivery or receipt of the energy
may be interrupted for any reason or no
reason, without liability on the part of
either the buyer or seller.
26......... Class Name....... [check].......... UP--Unit Power Designates a dedicated sale of energy and
Sale. capacity from one or more than one
specified generation unit(s).
26......... Class Name....... [check].......... N/A--Not To be used only when the other available
Applicable. Class Names do not apply.
27......... Term Name........ [check].......... LT--Long Term.... Contracts with durations of one year or
ST--Short Term... greater are long-term. Contracts with
N/A--Not shorter durations are short-term.
Applicable.
28......... Increment Name... [check].......... ................. See definitions for each increment below.
28......... Increment Name... [check].......... H--Hourly........ Terms of the contract (if specifically
noted in the contract) set for up to 6
consecutive hours (<= 6 consecutive
hours).
28......... Increment Name... [check].......... D--Daily......... Terms of the contract (if specifically
noted in the contract) set for more than
6 and up to 60 consecutive hours (> 6 and
<= 60 consecutive hours).
28......... Increment Name... [check].......... W--Weekly........ Terms of the contract (if specifically
noted in the contract) set for over 60
consecutive hours and up to 168
consecutive hours (> 60 and <= 168
consecutive hours).
28......... Increment Name... [check].......... M--Monthly....... Terms of the contract (if specifically
noted in the contract) set for more than
168 consecutive hours up to, but not
including, one year (> 168 consecutive
hours and < 1 year).
28......... Increment Name... [check].......... Y--Yearly........ Terms of the contract (if specifically
noted in the contract) set for one year
or more (>= 1 year).
28......... Increment Name... [check].......... N/A--Not Terms of the contract do not specify an
Applicable. increment.
29......... Increment Peaking [check].......... ................. See definitions for each increment peaking
Name. name below.
29......... Increment Peaking [check].......... FP--Full Period.. The product described may be sold during
Name. those hours designated as on-peak and off-
peak in the NERC region of the point of
delivery.
29......... Increment Peaking [check].......... OP--Off-Peak..... The product described may be sold only
Name. during those hours designated as off-peak
in the NERC region of the point of
delivery.
29......... Increment Peaking [check].......... P--Peak.......... The product described may be sold only
Name. during those hours designated as on-peak
in the NERC region of the point of
delivery.
29......... Increment Peaking [check].......... N/A--Not To be used only when the increment peaking
Name. Applicable. name is not specified in the contract.
30......... Product Type Name [check].......... ................. See definitions for each product type
below.
30......... Product Type Name [check].......... CB--Cost Based... Energy or capacity sold under a FERC-
approved cost-based rate tariff.
30......... Product Type Name [check].......... CR--Capacity An agreement under which a transmission
Reassignment. provider sells, assigns or transfers all
or portion of its rights to an eligible
customer.
30......... Product Type Name [check].......... MB--Market Based. Energy or capacity sold under the seller's
FERC-approved market-based rate tariff.
30......... Product Type Name [check].......... T--Transmission.. The product is sold under a FERC-approved
transmission tariff.
30......... Product Type Name [check].......... Other............ The product cannot be characterized by the
other product type names.
31......... Product Name..... [check].......... See Product Name Description of product being offered.
Table, Appendix
A.
32......... Quantity......... If specified in Number with up to Quantity for the contract product
the contract. 4 decimals. identified.
33......... Units............ If specified in See Units Table, Measure stated in the contract for the
the contract. Appendix E. product sold.
34......... Rate............. ................. Number with up to The charge for the product per unit as
4 decimals. stated in the contract.
35......... Rate Minimum..... One of four rate Number with up to Maximum rate to be charged per the
fields (34, 35, 4 decimals. contract, if a range is specified.
36, or 37) must
be included.
36......... Rate Maximum..... ................. Number with up to Maximum rate to be charged per the
4 decimals. contract, if a range is specified.
[[Page 1882]]
37......... Rate Description. Unrestricted text Text description of rate. If the rate is
currently available on the FERC Web site,
a citation of the FERC Accession Number
and the relevant FERC tariff including
page number or section may be included
instead of providing the entire rate
algorithm. If the rate is not available
on the FERC Web site, include the rate
algorithm, if rate is calculated. If the
algorithm would exceed the 150 character
field limit, it may be provided in a
descriptive summary (including bases and
methods of calculations) with a detailed
citation of the relevant FERC tariff
including page number and section. If
more than 150 characters are required,
the contract product may be repeated in a
subsequent line of data until the rate is
adequately described.
38......... Rate Units....... If specified in See Rate Units Measure stated in the contract for the
the contract. Table, Appendix product sold.
F.
39......... Point of Receipt If specified in See Balancing The registered NERC Balancing Authority
Balancing the contract. Authority Table, (formerly called NERC Control Area) where
Authority Appendix B. service begins for a transmission or
(PORBA). transmission-related jurisdictional sale.
The Balancing Authority will be
identified with the abbreviation used in
OASIS applications. If receipt occurs at
a trading hub specified in the EQR
software, the term ``Hub'' should be
used.
40......... Point of Receipt If specified in Unrestricted text The specific location at which the product
Specific the contract. (50 characters). is received if designated in the
Location (PORSL). If ``HUB'' is contract. If receipt occurs at a trading
selected for hub, a standardized hub name must be
PORCA, see Hub used. If more points of receipt are
Table, Appendix listed in the contract than can fit into
C. the 50 character space, a description of
the collection of points may be used.
`Various,' alone, is unacceptable unless
the contract itself uses that
terminology.
41......... Point of Delivery If specified in See Balancing The registered NERC Balancing Authority
Balancing the contract. Authority Table, (formerly called NERC Control Area) where
Authority Appendix B. a jurisdictional product is delivered and/
(PODBA). or service ends for a transmission or
transmission-related jurisdictional sale.
The Balancing Authority will be
identified with the abbreviation used in
OASIS applications. If delivery occurs at
the interconnection of two control areas,
the control area that the product is
entering should be used. If delivery
occurs at a trading hub specified in the
EQR software, the term ``Hub'' should be
used.
42......... Point of Delivery If specified in Unrestricted text The specific location at which the product
Specific the contract. (50 characters). is delivered if designated in the
Location (PODSL). If ``HUB'' is contract. If receipt occurs at a trading
selected for hub, a standardized hub name must be
PODCA, see Hub used.
Table, Appendix
C.
43......... Begin Date....... If specified in YYYYMMDDHHMM..... First date for the sale of the product at
the contract. the rate specified.
44......... End Date......... If specified in YYYYMMDDHHMM..... Last date for the sale of the product at
the contract. the rate specified.
45......... Time Zone........ [check].......... See Time Zone The time zone in which the sales will be
Table, Appendix made under the contract.
D.
----------------------------------------------------------------------------------------------------------------
Transaction Data
----------------------------------------------------------------------------------------------------------------
46......... Transaction [check].......... An integer An identifier beginning with the letter
Unique ID. proceeded by the ``T'' and followed by a number (e.g.,
letter ``T'' ``T1'', ``T2'') used to designate a
(only used when record containing transaction information
importing in a comma-delimited (csv) file that is
transaction imported into the EQR filing. One record
data). for each transaction record may be
imported into an EQR for a given quarter.
A new transaction record must be used
every time a price changes in a sale.
47......... Seller Company [check].......... Unrestricted text The name of the company that is authorized
Name. (100 Characters). to make sales as indicated in the
company's FERC tariff(s). This name must
match the name provided as a Seller's
``Company Name'' in Field 2 of the ID
Data (Seller Data).
48......... Customer Company [check].......... Unrestricted text The name of the counterparty.
Name. (70 Characters).
49......... Customer DUNS [check].......... Nine digit number The unique nine digit number assigned by
Number. Dun and Bradstreet to the counterparty to
the contract.
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50......... FERC Tariff [check].......... Unrestricted text The FERC tariff reference cites the
Reference. (60 Characters). document that specifies the terms and
conditions under which a Seller is
authorized to make transmission sales,
power sales or sales of related
jurisdictional services at cost-based
rates or at market-based rates. If the
sales are market-based, the tariff that
is specified in the FERC order granting
the Seller Market Based Rate Authority
must be listed.
51......... Contract Service [check].......... Unrestricted text Unique identifier given to each service
Agreement ID. (30 Characters). agreement that can be used by the filing
company to produce the agreement, if
requested. The identifier may be the
number assigned by FERC for those service
agreements that have been filed and
approved by the Commission, or it may be
generated as part of an internal
identification system.
52......... Transaction [check].......... Unrestricted text Unique reference number assigned by the
Unique (24 Characters). seller for each transaction.
Identifier.
53......... Transaction Begin [check].......... YYYYMMDDHHMM (csv First date and time the product is sold
Date. import). during the quarter.
MMDDYYYYHHMM
(manual entry).
54......... Transaction End [check].......... YYYYMMDDHHMM (csv Last date and time the product is sold
Date. import). during the quarter.
MMDDYYYYHHMM
(manual entry).
55......... Time Zone........ [check].......... See Time Zone The time zone in which the sales will be
Table, Appendix made under the contract.
D.
56......... Point of Delivery [check].......... See Balancing The registered NERC Balancing Authority
Balancing Authority Table, (formerly called NERC Control Area)
Authority Appendix B. abbreviation used in OASIS applications.
(PODBA).
57......... Point of Delivery [check].......... Unrestricted text The specific location at which the product
Specific (50 characters). is delivered. If receipt occurs at a
Location (PODSL). If ``HUB'' is trading hub, a standardized hub name must
selected for be used.
PODBA, see Hub
Table, Appendix
C.
58......... Class Name....... [check].......... ................. See class name definitions below.
58......... Class Name....... [check].......... F--Firm.......... A sale, service or product that is not
interruptible for economic reasons.
58......... Class Name....... [check].......... NF--Non-firm..... A sale for which delivery or receipt of
the energy may be interrupted for any
reason or no reason, without liability on
the part of either the buyer or seller.
58......... Class Name....... [check].......... UP--Unit Power Designates a dedicated sale of energy and
Sale. capacity from one or more than one
specified generation unit(s).
58......... Class Name....... [check].......... BA--Billing Designates an incremental material change
Adjustment. to one or more transactions due to a
change in settlement results. ``BA'' may
be used in a refiling after the next
quarter's filing is due to reflect the
receipt of new information. It may not be
used to correct an inaccurate filing.
58......... Class Name....... [check].......... N/A--Not To be used only when the other available
Applicable. class names do not apply.
59......... Term Name........ [check].......... LT--Long Term.... Power sales transactions with durations of
ST--Short Term... one year or greater are long-term.
N/A--Not Transactions with shorter durations are
Applicable. short-term.
60......... Increment Name... [check].......... ................. See increment name definitions below.
60......... Increment Name... [check].......... H--Hourly........ Terms of the particular sale set for up to
6 consecutive hours (<= 6 consecutive
hours) Includes LMP based sales in ISO/
RTO markets.
60......... Increment Name... [check].......... D--Daily......... Terms of the particular sale set for more
than 6 and up to 60 consecutive hours (>
6 and <= 60 consecutive hours) Includes
sales over a peak or off-peak block
during a single day.
60......... Increment Name... [check].......... W--Weekly........ Terms of the particular sale set for over
60 consecutive hours and up to 168
consecutive hours (> 60 and <= 168
consecutive hours). Includes sales for a
full week and sales for peak and off-peak
blocks over a particular week.
60......... Increment Name... [check].......... M--Monthly....... Terms of the particular sale set for set
for more than 168 consecutive hours up
to, but not including, one year (>168
consecutive hours and < 1 year). Includes
sales for full month or multi-week sales
during a given month.
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