Revised Public Utility Filing Requirements for Electric Quarterly Reports, 12983-12995 [E8-4753]
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
Kimberly D. Bose,
Secretary.
[FR Doc. E8–4735 Filed 3–10–08; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. RM01–8–009]
Revised Public Utility Filing
Requirements for Electric Quarterly
Reports
Issued March 3, 2008.
Federal Energy Regulatory
Commission, Department of Energy.
ACTION: Notice Seeking Comments on
Proposed Revisions to Electric Quarterly
Report (EQR) Data Dictionary.
yshivers on PROD1PC62 with NOTICES
AGENCY:
SUMMARY: In this notice, the Federal
Energy Regulatory Commission
(Commission) proposes to revise the
EQR Data Dictionary to clarify the
requirement to report all ancillary
service transactions, and invites
comments on this proposal. This
proposal is being made to reflect the
Commission’s decision in Order No. 697
that information about third party sales
of ancillary services at market-based
rates should be reported in EQR filings,
rather than being reported on a separate
OASIS-like Internet site. If adopted, this
proposal will make reporting this
information less burdensome and more
accessible.
DATES: Comments on the proposal are
due April 10, 2008.
ADDRESSES: You may submit comments
on the proposal, identified by Docket
No. RM01–8–009, by one of the
following methods:
• Agency Web Site: https://
www.ferc.gov. Follow the instructions
for submitting comments via the eFiling
link found in the Comment Procedures
Section of the preamble.
• Mail: Commenters unable to file
comments electronically must mail or
hand deliver an original and 14 copies
of their comments to the Federal Energy
Regulatory Commission, Secretary of the
Commission, 888 First Street, NE.,
Washington, DC 20426. Please refer to
the Comment Procedures Section of the
preamble for additional information on
how to file paper comments.
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.
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Gary D. Cohen (Legal Information),
Office of the General Counsel, Federal
Energy Regulatory Commission, 888
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. The Commission is proposing to
revise the Electric Quarterly Report
(EQR) Data Dictionary to clarify the
requirement to report all ancillary
service transactions and invites
comment on this proposal.
2. This proposal is being made to
reflect the Commission’s decision in
Order No. 697 that information about
third party sales of ancillary services at
market-based rates should be reported
in EQR filings, rather than being
reported on a separate OASIS-like
Internet site. If adopted, this proposal
will make reporting this information
less burdensome and more accessible.
Background
3. On April 25, 2002, the Commission
issued Order No. 2001, a Final Rule
establishing revised public utility filing
requirements.1 This rule revised the
Commission’s filing requirements to
require companies subject to the
Commission’s regulations under section
205 of the Federal Power Act2 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.
4. 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
1 Revised Public Utility Filing Requirements,
Order No. 2001, 67 FR 31043 (May 8, 2002), FERC
Stats. & Regs. ¶31,127 (Apr. 25, 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
No. 2001–D, order directing filings, 102 FERC
¶ 61,334, Order No. 2001–E, order refining filing
requirements, 105 FERC ¶61,352 (2003),
clarification order, Order No.2001–F, 106 FERC
¶61,060 (2004), order adopting EQR Data
Dictionary, Order No. 2001–G, 120 FERC ¶61,270
(2007), order on reh’g and clarification, Order No.
2001–H, 121 FERC ¶61,289 (2007).
2 16 U.S.C. 824d.
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12983
prepared in conformance with the
Commission’s software and guidance
posted and available from the
Commission Web site. This obviates the
need to revise 18 CFR 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.
5. On September 24, 2007, the
Commission issued Order No. 2001–G,
adopting an EQR Data Dictionary that
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 Web site) and providing
formal definitions for fields that were
previously undefined. On December 20,
2007, the Commission issued Order No.
2001–H, which addressed a pending
request for rehearing and clarifying the
information to be reported in several
EQR data fields.
6. On June 21, 2007, the Commission
issued Order No. 697,3 a Final Rule that
codified and, in certain respects, revised
the Commission’s standards for marketbased rates for sales of electric energy,
capacity, and ancillary services. The
rule retained several of the core
elements of the Commission’s existing
standards for granting market-based
rates and revised them in certain
respects. The rule also adopted a
number of reforms to streamline the
administration of the market-based rate
program. Among other issues addressed
in Order No. 697, the Commission
addressed the posting and reporting
requirements for third-party sellers of
ancillary services at market-based rates.
7. This matter had previously been
addressed in Avista Corporation, 87
FERC ¶61,223, order on reh’g, 89 FERC
¶61,136 (1999) (Avista), among other
cases. Prior to the issuance of Order No.
697, Avista provided a general policy
stating that third-party ancillary service
providers that could not perform a
market power study would be allowed
to sell ancillary services at market-based
rates, but only in conjunction with a
requirement that such third parties
establish an Internet-based, OASIS-like
site for providing information about and
transacting ancillary services. The
authorization in Avista extended only to
the following four ancillary services:
Regulation Service, Energy Imbalance
3 Market-Based Rates for Wholesale Sales of
Electric Energy, Capacity and Ancillary Services by
Public Utilities, Order No. 697, 72 FR 39904 (July
20, 2007), FERC Stats. & Regs. ¶31,252 (June 21,
2007), clarifying order, 122 FERC ¶61,260 (2007).
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
Service, Spinning Reserves, and
Supplemental Reserves.
8. In Order No. 697, the Commission
determined that it would modify its
prior approach to the posting and
reporting requirements for third-party
sellers of ancillary services at marketbased rates as announced in Avista.
Specifically, the Commission agreed
with comments arguing that the costs
and responsibilities associated with
establishing and maintaining an
Internet-based site may outweigh the
benefits that third-party sellers could
derive from the sale of the additional
products.
9. The Commission concluded that
the Commission’s EQR filing
requirement provides an adequate
means to monitor ancillary services
sales by third parties such that the
posting and reporting requirements
established in Avista are no longer
necessary.4 The Commission noted that,
through their EQR filings, third-party
providers of ancillary services provide
information regarding their ancillary
services transactions for each quarter,
including the ancillary service or
services provided, the price, and the
purchaser. As a result, the Commission
determined that it would no longer
require third-party providers of
ancillary services to establish and
maintain an Internet-based OASIS-like
site for providing information about
their ancillary services transactions.5
10. Additionally, in Order No. 890,
the Commission adopted a new
Schedule 9 for the treatment of
generator imbalances.6 In Order No.
2001–E, the Commission demonstrated
its intention to match the ancillary
service products included in the pro
forma open access transmission tariff
(OATT) by defining ancillary Product
Names as they were defined in the
OATT.7
Discussion
11. The Commission’s revised
requirements for the posting and
reporting requirements for third-party
sellers of ancillary services at marketbased rates in Order No. 697 depend on
sellers reporting, in the EQRs,
information previously required by
Avista to be reported and posted on an
OASIS-like Internet site. Therefore, in
4 Order
No. 697 at P 1058.
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5 Id.
6 Preventing Undue Discrimination and
Preference in Transmission Service, Order No. 890,
72 FR 12266 (Mar. 15, 2007), FERC Stats. & Regs.
¶31,241 at P 668 (Feb. 16, 2007), order on reh’g,
Order No. 890–A, 73 FR 2984 (Jan. 16, 2008), FERC
Stats. and Regs. ¶31,261 (2007).
7 The Order No. 888 OATT ancillary services
were Scheduling, System Control And Dispatch
(Schedule 1), Reactive Supply And Voltage Control
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order to clarify the reporting
requirements and to accommodate the
reporting of ancillary service
transactions, we propose to revise the
Product Name definitions of the
relevant ancillary services in Appendix
A of the EQR Data Dictionary. The
phrase ‘‘Reported for power sales and
transmission-related transactions’’ will
be added to the definitions for the four
Product Names identified in Avista—
Energy Imbalance, Regulation &
Frequency Response, Spinning Reserve,
Supplemental Reserve—to clarify that
sales of these services must be reported
both in the Contract and Transaction
sections of the EQR. We invite
comments on these proposed changes.
12. The Commission also proposes to
add the Product Name ‘‘Generator
Imbalance’’ to Appendix A of the EQR
Data Dictionary to maintain consistency
with the revised pro forma OATT.8 At
this time, we are not proposing to add
Product Names for ancillary services not
explicitly identified in Order No. 890.
We invite comments on whether there
are other ancillary services beyond
those identified in Order No. 890 that
should be identified explicitly in the
EQR.9 While the Commission does not
intend to add defined Product Names
for every kind of ancillary service
offered by every company, there may be
value to the public in identifying
common or important offerings as such,
rather than as the catchall ‘‘OTHER’’ in
future EQRs.
Comment Procedures
13. The Commission invites interested
persons to submit comments on the
matters and issues proposed in this
notice, including any related matters or
alternative proposals that commenters
may wish to discuss. Comments are due
April 10, 2008. Comments must refer to
Docket No. RM01–8–009, and must
include the commenter’s name, the
organization they represent, if
applicable, and their address.
Comments may be filed either in
electronic or paper format.
14. Comments may be filed
electronically via the eFiling link on the
Commission’s Web site at https://
www.ferc.gov. The Commission accepts
most standard word processing formats
and commenters may attach additional
(Schedule 2), Regulation And Frequency Response
(Schedule 3), Energy Imbalance (Schedule 4),
Operating Reserve—Spinning—or Spinning
Reserve—(Schedule 5), Operating Reserve—
Supplemental—or Supplemental Reserve—
(Schedule 6). These same services are now offered
under the Order No. 890 pro forma OATT.
8 Order No. 890, pro forma OATT at Schedule 9,
provides that ‘‘Generator Imbalance Service is
provided when a difference occurs between the
output of a generator located in the Transmission
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files with supporting information in
certain other file formats. Commenters
filing electronically do not need to make
a paper filing. Commenters that are not
able to file comments electronically
must send an original and 14 copies of
their comments to: Federal Energy
Regulatory Commission, Secretary of the
Commission, 888 First Street, NE.,
Washington, DC 20426.
15. All comments will be placed in
the Commission’s public files and may
be viewed, printed, or downloaded
remotely as described in the Document
Availability section below. Commenters
on this proposal are not required to
serve copies of their comments on other
commenters.
Document Availability
16. 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.
17. 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 the docket
number excluding the last three digits of
this document in the docket number
field.
18. User assistance is available for
eLibrary and the Commission’s Web site
during our normal business hours. For
assistance contact FERC Online Support
at FERCOnlineSupport@ferc.gov or tollfree at (866) 208–3676, or for TTY,
contact (202) 502–8659.
By direction of the Commission.
Kimberly D. Bose,
Secretary.
Attachment A—Proposed Revisions to
Electric Quarterly Report Data
Dictionary Version 1.1 (issued
December 21, 2007)
Provider’s Control Area and a delivery schedule
from that generator to (1) another Control Area or
(2) a load within the Transmission Provider’s
Control Area over a single hour.’’ Schedule 9 also
prescribes how the charges for this service are to
be developed.
9 For example, the Commission found that
Dynamic Capacity and Energy Service as described
in Avista is an ancillary service governed by
Avista’s ancillary service tariff. See Avista, 89 FERC
¶61,136 at 61,392.
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12985
QR DATA DICTIONARY—ID DATA
Field
Required
Value
Definition
1 ..........
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
for Respondent and Seller.
4 ..........
Contact Name ................
Unrestricted text (50
characters).
4 ..........
Contact Name ................
Unrestricted text (50
characters).
4 ..........
Contact Name ................
5 ..........
Contact Title ...................
Contact Address .............
Unrestricted text (50
characters).
Unrestricted text (50
characters).
Unrestricted text .............
(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 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.
(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.
6 ..........
7 ..........
Contact City ....................
8 ..........
Contact State .................
9 ..........
Contact Zip .....................
10 ........
Contact Country Name ..
11 ........
Contact Phone ...............
12 ........
Contact E-Mail ................
Unrestricted text (30
characters).
Unrestricted text (2 characters).
Unrestricted text (10
characters).
CA–Canada MX–Mexico
US–United States UK–
United Kingdom.
Unrestricted text (20
characters).
Unrestricted text .............
13 ........
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Field
No.
Filing Quarter .................
YYYYMM ........................
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Nine digit number ...........
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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.
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).
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QR DATA DICTIONARY—CONTRACT DATA
Field
Required
Value
Definition
14 ........
Contract Unique ID ...............
An integer proceeded by the
letter ‘‘C’’ (only used when
importing contract data).
15 ........
Seller Company Name ..........
Unrestricted text (100 characters).
16 ........
Customer Company Name ...
Customer DUNS Number .....
Unrestricted text (70 characters).
Nine digit number ..................
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.
17 ........
18 ........
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 .......
YYYYMMDD .........................
22 ........
Contract Commencement
Date.
YYYYMMDD .........................
23 ........
Contract Termination Date ....
YYYYMMDD .........................
Actual Termination Date Extension.
YYYYMMDD .........................
The date the contract actually terminates.
25 ........
Provision Description ............
If specified in
the
contract.
If contract
terminated.
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 marketbased, 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 Contract
Data section of the EQR were effective. If the terms reported in 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.
24 ........
Unrestricted text ....................
26 ........
26 ........
Class Name ..........................
Class Name ..........................
...............................................
F–Firm ...................................
26 ........
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Field
No.
Class Name ..........................
NF—Non-firm ........................
26 ........
Class Name ..........................
UP—Unit Power Sale ...........
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.
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).
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12987
QR DATA DICTIONARY—CONTRACT DATA—Continued
Field
Required
Value
Definition
26 ........
Class Name ..........................
N/A–Not Applicable ...............
27 ........
Term Name ...........................
28 ........
28 ........
Increment Name ...................
Increment Name ...................
LT–Long Term ST–Short
Term N/A—Not Applicable.
...........................................
H–Hourly ...............................
28 ........
Increment Name ...................
D–Daily ..................................
28 ........
Increment Name ...................
W–Weekly .............................
28 ........
Increment Name ...................
M–Monthly .............................
28 ........
Increment Name ...................
Y–Yearly ................................
28 ........
29 ........
29 ........
Increment Name ...................
Increment Peaking Name .....
Increment Peaking Name .....
N/A–Not Applicable ...............
...........................................
FP–Full Period ......................
29 ........
Increment Peaking Name .....
OP–Off-Peak .........................
29 ........
Increment Peaking Name .....
P–Peak ..................................
29 ........
Increment Peaking Name .....
N/A–Not Applicable ...............
30 ........
30 ........
Product Type Name ..............
Product Type Name ..............
...........................................
CB–Cost Based ....................
30 ........
Product Type Name ..............
CR–Capacity Reassignment
30 ........
Product Type Name ..............
MB–Market Based ................
30 ........
Product Type Name ..............
T–Transmission .....................
30 ........
Product Type Name ..............
Other .....................................
31 ........
Product Name .......................
Quantity .................................
See Product Name Table,
Appendix A..
Number with up to 4 decimals.
To be used only when the other available Class Names do
not apply.
Contracts with durations of one year or greater are longterm. Contracts with shorter durations are short-term.
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 costbased 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
market-based rate tariff.
The product is sold under a FERC-approved transmission
ariff.
The product cannot be characterized by the other product
type names.
Description of product being offered.
32 ........
33 ........
Units ......................................
34 ........
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Field
No.
Rate .......................................
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If specified in
the
contract.
If speciSee Units Table, Appendix E.
fied in
the
contract.
One of
Number with up to 4 decifour
mals.
rate
fields
(34,
35,
36, or
37)
must
be included.
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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.
E:\FR\FM\11MRN1.SGM
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—CONTRACT DATA—Continued
Field
No.
Field
35 ........
Rate Minimum .......................
36 ........
Rate Maximum ......................
37 ........
Rate Description ...................
38 ........
Rate Units .............................
39 ........
Point of Receipt Balancing
Authority (PORBA).
40 ........
Required
Value
Definition
One of
Number with up to 4 decifour
mals.
rate
fields
(34,
35,
36, or
37)
must
be included.
One of
Number with up to 4 decifour
mals.
rate
fields
(34,
35,
36, or
37)
must
be included.
One of
Unrestricted text ....................
four
rate
fields
(34,
35,
36, or
37)
must
be included.
See Rate Units Table, Appendix F.
Point of Receipt Specific Location (PORSL).
If specified in
the
contract.
Unrestricted text (50 characters). If ‘‘HUB’’ is selected for PORCA, see
Hub Table, Appendix C.
41 ........
yshivers on PROD1PC62 with NOTICES
If specified in
the
contract.
If specified in
the
contract.
Point of Delivery Balancing
Authority(PODBA).
If specified in
the
contract.
See Balancing Authority
Table, Appendix B.
42 ........
Point of Delivery Specific Location (PODSL).
If specified in
the
contract.
Unrestricted text (50 characters). If ‘‘HUB’’ is selected for PODCA, see
Hub Table, Appendix C.
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Minimum 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.
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.
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.
E:\FR\FM\11MRN1.SGM
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
12989
QR DATA DICTIONARY—CONTRACT DATA—Continued
Field
No.
Field
Required
Value
43 ........
Begin Date ............................
YYYYMMDDHHMM ..............
First date for the sale of the product at the rate specified.
44 ........
End Date ...............................
YYYYMMDDHHMM ..............
Last date for the sale of the product at the rate specified.
45 ........
Time Zone .............................
If specified in
the
contract.
If specified in
the
contract.
See Time Zone Table, Appendix D.
The time zone in which the sales will be made under the
contract.
Definition
QR DATA DICTIONARY—TRANSACTION DATA
Field
Required
Value
Definition
46 ........
Transaction Unique ID ...
An integer proceeded by
the letter ‘‘T’’ (only
used when importing
transaction data).
47 ........
Seller Company Name ...
Unrestricted text (100
Characters).
48 ........
Customer Company
Name.
Customer DUNS Number
Unrestricted text (70
Characters).
Nine digit number ...........
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.
49 ........
50 ........
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 ........
yshivers on PROD1PC62 with NOTICES
Field
No.
Transaction End Date ....
55 ........
Time Zone ......................
56 ........
Point of Delivery Balancing Authority
(PODBA).
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.
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The unique nine digit number assigned by Dun
and Bradstreet to the counterparty to the contract.
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 marketbased 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.
E:\FR\FM\11MRN1.SGM
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—TRANSACTION DATA—Continued
Field
Required
Value
Definition
57 ........
Point of Delivery Specific
Location (PODSL).
Class Name ....................
Class Name ....................
Unrestricted text (50
characters). If ‘‘HUB’’
is selected for PODBA,
see Hub Table, Appendix C.
....................................
F–Firm ............................
The specific location at which the product is delivered. If receipt occurs at a trading hub, a standardized hub name must be used.
58 ........
58 ........
58 ........
Class Name ....................
NF–Non-firm ...................
58 ........
Class Name ....................
UP–Unit Power Sale ......
58 ........
Class Name ....................
BA–Billing Adjustment ....
58 ........
Class Name ....................
N/A–Not Applicable ........
59 ........
Term Name ....................
60 ........
60 ........
Increment Name .............
Increment Name .............
LT–Long Term ................
ST—Short Term .............
N/A–Not Applicable ........
....................................
H–Hourly ........................
60 ........
Increment Name .............
D–Daily ...........................
60 ........
Increment Name .............
W–Weekly ......................
60 ........
Increment Name .............
M–Monthly ......................
60 ........
Increment Name .............
Y–Yearly .........................
60 ........
Increment Name .............
N/A–Not Applicable ........
61 ........
61 ........
Increment Peaking Name
Increment Peaking Name
....................................
FP–Full Period ...............
61 ........
Increment Peaking Name
OP–Off-Peak ..................
61 ........
Increment Peaking Name
P–Peak ...........................
61 ........
Increment Peaking Name
N/A–Not Applicable ........
62 ........
yshivers on PROD1PC62 with NOTICES
Field
No.
Product Name ................
63 ........
Transaction Quantity ......
64 ........
Price ...............................
See Product Names
Table, Appendix A.
Number with up to 4
decimals.
Number with up to 6
decimals.
65 ........
Rate Units ......................
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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 multiweek sales during a given month.
Terms of the particular sale set for one year or
more (≥ 1 year). Includes all long-term contracts
with defined pricing terms (fixed-price, formula,
or index).
To be used only when other available increment
names do not apply.
See definitions for increment peaking below.
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.
E:\FR\FM\11MRN1.SGM
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12991
QR DATA DICTIONARY—TRANSACTION DATA—Continued
Field
No.
Field
Required
66 ........
Total Transmission
Charge.
Total Transaction Charge
67 ........
Value
Definition
Number with up to 2
decimals.
Number with up to 2
decimals.
Payments received for transmission services when
explicitly identified.
Transaction Quantity (Field 63) times Price (Field
64) plus Total Transmission Charge (Field 66).
QR DATA DICTIONARY—APPENDIX A. PRODUCT NAMES
Contract
product
Transaction
product
Definition
BLACK START SERVICE ................
BOOKED OUT POWER ...................
........................
CAPACITY ........................................
CUSTOMER CHARGE .....................
DIRECT ASSIGNMENT FACILITIES
CHARGE.
EMERGENCY ENERGY ..................
........................
........................
ENERGY ...........................................
ENERGY IMBALANCE .....................
EXCHANGE ......................................
FUEL CHARGE ................................
GENERATOR IMBALANCE .............
GRANDFATHERED BUNDLED .......
INTERCONNECTION AGREEMENT
........................
MEMBERSHIP AGREEMENT ..........
MUST RUN AGREEMENT ...............
NEGOTIATED-RATE
TRANSMISSION.
NETWORK ........................................
NETWORK OPERATING AGREEMENT.
........................
........................
........................
........................
OTHER .............................................
POINT-TO-POINT AGREEMENT .....
........................
REACTIVE SUPPLY & VOLTAGE
CONTROL.
REAL POWER TRANSMISSION
LOSS.
REGULATION & FREQUENCY RESPONSE.
yshivers on PROD1PC62 with NOTICES
Product name
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. Reported for power
sales and transmission-related transactions.
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.
Service provided when a difference occurs between the output of a
generator located in the Transmission Provider’s Control Area and a
delivery schedule from that generator to (1) another Control Area or
(2) a load within the Transmission Provider’s Control Area over a
single hour. Reported for power sales and transmission-related
transactions.
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.
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). Reported for power sales
and transmission-related transactions.
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—APPENDIX A. PRODUCT NAMES—Continued
Product name
Contract
product
Transaction
product
Definition
REQUIREMENTS SERVICE ............
SCHEDULE SYSTEM CONTROL &
DISPATCH.
SPINNING RESERVE ......................
SUPPLEMENTAL RESERVE ...........
SYSTEM OPERATING
MENTS.
AGREE-
........................
TOLLING ENERGY ..........................
TRANSMISSION
AGREEMENT.
OWNERS
........................
UPLIFT ..............................................
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). Reported for power sales and transmission-related transactions.
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). Reported for power sales and transmission-related transactions.
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.
QR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY
yshivers on PROD1PC62 with NOTICES
Balancing authority
Abbreviation
Outside
US *
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 .......................................................................................................................
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 ..............................................................................................................................................................
AEWC ..........
AEC ..............
AESO ...........
ALTE ............
ALTW ...........
AMRN ..........
AMIL .............
AMMO ..........
FE ................
WPEK ..........
MPS .............
WPEC ..........
AZPS ............
AECI .............
AVA ..............
BBA ..............
BREC ...........
KACY ...........
BPAT ............
BCTC ...........
CISO ............
CPLW ...........
CPLE ............
CSWS ..........
CILC .............
CHPD ...........
CIN ...............
HST ..............
INDN ............
TAL ..............
CWLP ...........
CLEC ...........
................
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E:\FR\FM\11MRN1.SGM
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued
yshivers on PROD1PC62 with NOTICES
Balancing authority
Abbreviation
Outside
US *
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, AK ................................................................................
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 .............................................................................................................................
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 ....................................................................................................................................................................
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 ...........
CONS ...........
DECO ...........
MEC .............
MISO ............
MP ................
MDU .............
MPW ............
NPPD ...........
NEVP ...........
NBPC ...........
NHC1 ...........
NYIS .............
TEST ............
NIPS .............
NSP ..............
NWMT ..........
OVEC ...........
OKGE ...........
IMO ..............
OPPD ...........
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued
Balancing authority
Abbreviation
Outside
US *
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 ........................................................................................................................................................................
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 ..............
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
................
* 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.
QR 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 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’’) 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’’) defined by the Midwest Independent Transmission System Operator, Inc., as FE Hub (MISO).
AEPGenHub ............................................
COB .........................................................
yshivers on PROD1PC62 with NOTICES
Cinergy (into) ...........................................
Cinergy Hub (MISO) ................................
Entergy (into) ...........................................
FE Hub ....................................................
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Federal Register / Vol. 73, No. 48 / Tuesday, March 11, 2008 / Notices
QR DATA DICTIONARY—APPENDIX C. HUB—Continued
HUB
Definition
Four Corners ...........................................
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’’) 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’’) 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’’) defined by the Midwest Independent Transmission System Operator, Inc., as Minnesota Hub (MISO).
The aggregated Locational Marginal Price (‘‘LMP’’) defined by ISO New England Inc., as Mass Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) 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’’) defined by PJM Interconnection, LLC as the PJM
South Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) 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.
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 ........................................................
QR DATA DICTIONARY—APPENDIX D.
TIME ZONE
Time zone
Definition
AD .............................
AP .............................
AS .............................
CD .............................
CP .............................
CS .............................
ED .............................
EP .............................
ES .............................
MD ............................
MP ............................
MS ............................
NA .............................
PD .............................
PP .............................
PS .............................
UT .............................
yshivers on PROD1PC62 with NOTICES
QR DATA DICTIONARY—APPENDIX E.
UNITS—Continued
QR DATA DICTIONARY—APPENDIX F.
RATE UNITS—Continued
Units
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.
Pacific Prevailing.
Pacific Standard.
Universal Time.
QR DATA DICTIONARY—APPENDIX E.
UNITS
Definition
Rate units
Definition
KW ...................
KWH ................
KW–DAY ..........
KW–MO ...........
KW–WK ...........
KW–YR ............
MVAR–YR .......
MW ..................
MWH ................
MW–DAY .........
MW–MO ...........
MW–WK ...........
MW–YR ...........
RKVA ...............
FLAT RATE .....
Kilowatt.
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.
$/KW–DAY
$/KW–MO ...
$/KW–WK ...
$/KW–YR ....
$/MW ..........
$/MWH .......
$/MW–DAY
$/MW–MO ..
$/MW–WK ..
$/MW–YR ...
$/MVAR–YR
$/RKVA .......
dollars per kilowatt day.
dollars per kilowatt month.
dollars per kilowatt week.
dollars per kilowatt year.
dollars per megawatt.
dollars per megawatt hour.
dollars per megawatt day.
dollars per megawatt month.
dollars per megawatt week.
dollars per megawatt year.
dollars per megavar year.
dollars per reactive kilovar amperes.
cents.
cents per kilovolt amperes.
cents per kilowatt hour.
QR DATA DICTIONARY—APPENDIX F.
RATE UNITS
Rate units
CENTS .......
CENTS/KVR
CENTS/
KWH.
FLAT RATE
rate not specified in any other
units.
Definition
[FR Doc. E8–4753 Filed 3–10–08; 8:45 am]
Units
Definition
KV ....................
KVA ..................
KVR .................
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Kilovolt Amperes.
Kilovar.
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$/KVA .........
$/KVR .........
$/KW ...........
$/KWH ........
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dollars
dollars
dollars
dollars
per
per
per
per
per
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kilovolt amperes.
kilovar.
kilowatt.
kilowatt hour.
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BILLING CODE 6717–01–P
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]]>Agencies
[Federal Register Volume 73, Number 48 (Tuesday, March 11, 2008)]
[Notices]
[Pages 12983-12995]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E8-4753]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
[Docket No. RM01-8-009]
Revised Public Utility Filing Requirements for Electric Quarterly
Reports
Issued March 3, 2008.
AGENCY: Federal Energy Regulatory Commission, Department of Energy.
ACTION: Notice Seeking Comments on Proposed Revisions to Electric
Quarterly Report (EQR) Data Dictionary.
-----------------------------------------------------------------------
SUMMARY: In this notice, the Federal Energy Regulatory Commission
(Commission) proposes to revise the EQR Data Dictionary to clarify the
requirement to report all ancillary service transactions, and invites
comments on this proposal. This proposal is being made to reflect the
Commission's decision in Order No. 697 that information about third
party sales of ancillary services at market-based rates should be
reported in EQR filings, rather than being reported on a separate
OASIS-like Internet site. If adopted, this proposal will make reporting
this information less burdensome and more accessible.
DATES: Comments on the proposal are due April 10, 2008.
ADDRESSES: You may submit comments on the proposal, identified by
Docket No. RM01-8-009, by one of the following methods:
Agency Web Site: https://www.ferc.gov. Follow the
instructions for submitting comments via the eFiling link found in the
Comment Procedures Section of the preamble.
Mail: Commenters unable to file comments electronically
must mail or hand deliver an original and 14 copies of their comments
to the Federal Energy Regulatory Commission, Secretary of the
Commission, 888 First Street, NE., Washington, DC 20426. Please refer
to the Comment Procedures Section of the preamble for additional
information on how to file paper comments.
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 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. The Commission is proposing to revise the Electric Quarterly
Report (EQR) Data Dictionary to clarify the requirement to report all
ancillary service transactions and invites comment on this proposal.
2. This proposal is being made to reflect the Commission's decision
in Order No. 697 that information about third party sales of ancillary
services at market-based rates should be reported in EQR filings,
rather than being reported on a separate OASIS-like Internet site. If
adopted, this proposal will make reporting this information less
burdensome and more accessible.
Background
3. On April 25, 2002, the Commission issued Order No. 2001, a Final
Rule establishing revised public utility filing requirements.\1\ 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\2\ 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, Order No. 2001,
67 FR 31043 (May 8, 2002), FERC Stats. & Regs. ]31,127 (Apr. 25,
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 No. 2001-D, order directing filings, 102 FERC ]
61,334, Order No. 2001-E, order refining filing requirements, 105
FERC ]61,352 (2003), clarification order, Order No.2001-F, 106 FERC
]61,060 (2004), order adopting EQR Data Dictionary, Order No. 2001-
G, 120 FERC ]61,270 (2007), order on reh'g and clarification, Order
No. 2001-H, 121 FERC ]61,289 (2007).
\2\ 16 U.S.C. 824d.
---------------------------------------------------------------------------
4. 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 Web site. This obviates the
need to revise 18 CFR 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.
5. On September 24, 2007, the Commission issued Order No. 2001-G,
adopting an EQR Data Dictionary that 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 Web site) and providing formal definitions
for fields that were previously undefined. On December 20, 2007, the
Commission issued Order No. 2001-H, which addressed a pending request
for rehearing and clarifying the information to be reported in several
EQR data fields.
6. On June 21, 2007, the Commission issued Order No. 697,\3\ a
Final Rule that codified and, in certain respects, revised the
Commission's standards for market-based rates for sales of electric
energy, capacity, and ancillary services. The rule retained several of
the core elements of the Commission's existing standards for granting
market-based rates and revised them in certain respects. The rule also
adopted a number of reforms to streamline the administration of the
market-based rate program. Among other issues addressed in Order No.
697, the Commission addressed the posting and reporting requirements
for third-party sellers of ancillary services at market-based rates.
---------------------------------------------------------------------------
\3\ Market-Based Rates for Wholesale Sales of Electric Energy,
Capacity and Ancillary Services by Public Utilities, Order No. 697,
72 FR 39904 (July 20, 2007), FERC Stats. & Regs. ]31,252 (June 21,
2007), clarifying order, 122 FERC ]61,260 (2007).
---------------------------------------------------------------------------
7. This matter had previously been addressed in Avista Corporation,
87 FERC ]61,223, order on reh'g, 89 FERC ]61,136 (1999) (Avista), among
other cases. Prior to the issuance of Order No. 697, Avista provided a
general policy stating that third-party ancillary service providers
that could not perform a market power study would be allowed to sell
ancillary services at market-based rates, but only in conjunction with
a requirement that such third parties establish an Internet-based,
OASIS-like site for providing information about and transacting
ancillary services. The authorization in Avista extended only to the
following four ancillary services: Regulation Service, Energy Imbalance
[[Page 12984]]
Service, Spinning Reserves, and Supplemental Reserves.
8. In Order No. 697, the Commission determined that it would modify
its prior approach to the posting and reporting requirements for third-
party sellers of ancillary services at market-based rates as announced
in Avista. Specifically, the Commission agreed with comments arguing
that the costs and responsibilities associated with establishing and
maintaining an Internet-based site may outweigh the benefits that
third-party sellers could derive from the sale of the additional
products.
9. The Commission concluded that the Commission's EQR filing
requirement provides an adequate means to monitor ancillary services
sales by third parties such that the posting and reporting requirements
established in Avista are no longer necessary.\4\ The Commission noted
that, through their EQR filings, third-party providers of ancillary
services provide information regarding their ancillary services
transactions for each quarter, including the ancillary service or
services provided, the price, and the purchaser. As a result, the
Commission determined that it would no longer require third-party
providers of ancillary services to establish and maintain an Internet-
based OASIS-like site for providing information about their ancillary
services transactions.\5\
---------------------------------------------------------------------------
\4\ Order No. 697 at P 1058.
\5\ Id.
---------------------------------------------------------------------------
10. Additionally, in Order No. 890, the Commission adopted a new
Schedule 9 for the treatment of generator imbalances.\6\ In Order No.
2001-E, the Commission demonstrated its intention to match the
ancillary service products included in the pro forma open access
transmission tariff (OATT) by defining ancillary Product Names as they
were defined in the OATT.\7\
---------------------------------------------------------------------------
\6\ Preventing Undue Discrimination and Preference in
Transmission Service, Order No. 890, 72 FR 12266 (Mar. 15, 2007),
FERC Stats. & Regs. ]31,241 at P 668 (Feb. 16, 2007), order on
reh'g, Order No. 890-A, 73 FR 2984 (Jan. 16, 2008), FERC Stats. and
Regs. ]31,261 (2007).
\7\ The Order No. 888 OATT ancillary services were Scheduling,
System Control And Dispatch (Schedule 1), Reactive Supply And
Voltage Control (Schedule 2), Regulation And Frequency Response
(Schedule 3), Energy Imbalance (Schedule 4), Operating Reserve--
Spinning--or Spinning Reserve--(Schedule 5), Operating Reserve--
Supplemental--or Supplemental Reserve--(Schedule 6). These same
services are now offered under the Order No. 890 pro forma OATT.
---------------------------------------------------------------------------
Discussion
11. The Commission's revised requirements for the posting and
reporting requirements for third-party sellers of ancillary services at
market-based rates in Order No. 697 depend on sellers reporting, in the
EQRs, information previously required by Avista to be reported and
posted on an OASIS-like Internet site. Therefore, in order to clarify
the reporting requirements and to accommodate the reporting of
ancillary service transactions, we propose to revise the Product Name
definitions of the relevant ancillary services in Appendix A of the EQR
Data Dictionary. The phrase ``Reported for power sales and
transmission-related transactions'' will be added to the definitions
for the four Product Names identified in Avista--Energy Imbalance,
Regulation & Frequency Response, Spinning Reserve, Supplemental
Reserve--to clarify that sales of these services must be reported both
in the Contract and Transaction sections of the EQR. We invite comments
on these proposed changes.
12. The Commission also proposes to add the Product Name
``Generator Imbalance'' to Appendix A of the EQR Data Dictionary to
maintain consistency with the revised pro forma OATT.\8\ At this time,
we are not proposing to add Product Names for ancillary services not
explicitly identified in Order No. 890. We invite comments on whether
there are other ancillary services beyond those identified in Order No.
890 that should be identified explicitly in the EQR.\9\ While the
Commission does not intend to add defined Product Names for every kind
of ancillary service offered by every company, there may be value to
the public in identifying common or important offerings as such, rather
than as the catchall ``OTHER'' in future EQRs.
---------------------------------------------------------------------------
\8\ Order No. 890, pro forma OATT at Schedule 9, provides that
``Generator Imbalance Service is provided when a difference occurs
between the output of a generator located in the Transmission
Provider's Control Area and a delivery schedule from that generator
to (1) another Control Area or (2) a load within the Transmission
Provider's Control Area over a single hour.'' Schedule 9 also
prescribes how the charges for this service are to be developed.
\9\ For example, the Commission found that Dynamic Capacity and
Energy Service as described in Avista is an ancillary service
governed by Avista's ancillary service tariff. See Avista, 89 FERC
]61,136 at 61,392.
---------------------------------------------------------------------------
Comment Procedures
13. The Commission invites interested persons to submit comments on
the matters and issues proposed in this notice, including any related
matters or alternative proposals that commenters may wish to discuss.
Comments are due April 10, 2008. Comments must refer to Docket No.
RM01-8-009, and must include the commenter's name, the organization
they represent, if applicable, and their address. Comments may be filed
either in electronic or paper format.
14. Comments may be filed electronically via the eFiling link on
the Commission's Web site at https://www.ferc.gov. The Commission
accepts most standard word processing formats and commenters may attach
additional files with supporting information in certain other file
formats. Commenters filing electronically do not need to make a paper
filing. Commenters that are not able to file comments electronically
must send an original and 14 copies of their comments to: Federal
Energy Regulatory Commission, Secretary of the Commission, 888 First
Street, NE., Washington, DC 20426.
15. All comments will be placed in the Commission's public files
and may be viewed, printed, or downloaded remotely as described in the
Document Availability section below. Commenters on this proposal are
not required to serve copies of their comments on other commenters.
Document Availability
16. 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.
17. 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 the docket number excluding the last three
digits of this document in the docket number field.
18. User assistance is available for eLibrary and the Commission's
Web site during our normal business hours. For assistance contact FERC
Online Support at FERCOnlineSupport@ferc.gov or toll-free at (866) 208-
3676, or for TTY, contact (202) 502-8659.
By direction of the Commission.
Kimberly D. Bose,
Secretary.
Attachment A--Proposed Revisions to Electric Quarterly Report Data
Dictionary Version 1.1 (issued December 21, 2007)
[[Page 12985]]
QR Data Dictionary--ID Data
----------------------------------------------------------------------------------------------------------------
Field No. Field Required Value Definition
----------------------------------------------------------------------------------------------------------------
1............... Filer Unique [check] FR1.................. (Respondent)--An
Identifier. 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.
1............... Filer Unique [check] FS (where (Seller)--An identifier
Identifier. ``'' is an (e.g., ``FS1'', ``FS2'')
integer). used to designate a
record containing Seller
identification
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
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.
2............... Company Name......... [check] Unrestricted text (Respondent)--The name of
(100 characters). the company taking
responsibility for
complying with the
Commission's regulations
related to the EQR.
2............... Company Name......... [check] Unrestricted text (Seller)--The name of the
(100 characters). 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.
2............... Company Name......... [check] Unrestricted text (Agent)--The name of the
(100 characters). entity completing the
EQR filing. The Agent's
Company Name need not be
the name of the company
under Commission
jurisdiction.
3............... Company DUNS Number.. for Respondent and Nine digit number.... The unique nine digit
Seller. number assigned by Dun
and Bradstreet to the
company identified in
Field Number 2.
4............... Contact Name......... [check] Unrestricted text (50 (Respondent)--Name of the
characters). person at the
Respondent's company
taking responsibility
for compliance with the
Commission's EQR
regulations.
4............... Contact Name......... [check] Unrestricted text (50 (Seller)--The name of the
characters). 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.
4............... Contact Name......... [check] Unrestricted text (50 (Agent)--Name of the
characters). contact for the Agent,
usually the person who
prepares the filing.
5............... Contact Title........ [check] Unrestricted text (50 Title of contact
characters). identified in Field
Number 4.
6............... Contact Address...... [check] Unrestricted text.... Street address for
contact identified in
Field Number 4.
7............... Contact City......... [check] Unrestricted text (30 City for the contact
characters). identified in Field
Number 4.
8............... Contact State........ [check] Unrestricted text (2 Two character state or
characters). province abbreviations
for the contact
identified in Field
Number 4.
9............... Contact Zip.......... [check] Unrestricted text (10 Zip code for the contact
characters). identified in Field
Number 4.
10.............. Contact Country Name. [check] CA-Canada MX-Mexico Country (USA, Canada,
US-United States UK- Mexico, or United
United Kingdom. Kingdom) for contact
address identified in
Field Number 4.
11.............. Contact Phone........ [check] Unrestricted text (20 Phone number of contact
characters). identified in 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).
----------------------------------------------------------------------------------------------------------------
[[Page 12986]]
QR Data Dictionary--Contract Data
----------------------------------------------------------------------------------------------------------------
Field No. Field Required Value Definition
----------------------------------------------------------------------------------------------------------------
14......... Contract Unique ID... [check] An integer proceeded An identifier beginning with the letter
by the letter ``C'' ``C'' and followed by a number (e.g.,
(only used when ``C1'', ``C2'') used to designate a
importing contract record containing contract information
data). 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.
15......... Seller Company Name.. [check] Unrestricted text The name of the company that is
(100 characters). 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).
16......... Customer Company Name [check] Unrestricted text (70 The name of the counterparty.
characters).
17......... Customer DUNS Number. [check] Nine digit number.... The unique nine digit number assigned by
Dun and Bradstreet to the company
identified in Field Number 16.
18......... Contract Affiliate... [check] Y (Yes).............. The customer is an affiliate if it
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 Reference [check] Unrestricted text (60 The FERC tariff reference cites the
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 (30 Unique identifier given to each service
Agreement ID. 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 Execution [check] YYYYMMDD............. The date the contract was signed. If the
Date. parties signed on different dates, use
the most recent date signed.
22......... Contract Commencement [check] YYYYMMDD............. The date the terms of the contract
Date. reported in the Contract Data section
of the EQR were effective. If the terms
reported in 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 Termination If YYYYMMDD............. The date that the contract expires.
Date. specified
in the
contract.
24......... Actual Termination If contract YYYYMMDD............. The date the contract actually
Date Extension. terminated. terminates.
25......... Provision Description [check] Unrestricted text.... Description of terms that provide for
the continuation of the contract.
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.
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 Sale.. Designates a dedicated sale of energy
and capacity from one or more than one
specified generation unit(s).
[[Page 12987]]
26......... Class Name........... [check] N/A-Not Applicable... To be used only when the other available
Class Names do not apply.
27......... Term Name............ [check] LT-Long Term ST-Short Contracts with durations of one year or
Term N/A--Not greater are long-term. Contracts with
Applicable. shorter durations are short-term.
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 Applicable... Terms of the contract do not specify an
increment.
29......... Increment Peaking [check] ..................... See definitions for each increment
Name. peaking 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 Applicable... To be used only when the increment
Name. peaking 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 ariff.
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 Number with up to 4 Quantity for the contract product
specified decimals. identified.
in the
contract.
33......... Units................ If See Units Table, Measure stated in the contract for the
specified Appendix E.. product sold.
in the
contract.
34......... Rate................. One of four Number with up to 4 The charge for the product per unit as
rate decimals. stated in the contract.
fields
(34, 35,
36, or 37)
must be
included.
[[Page 12988]]
35......... Rate Minimum......... One of four Number with up to 4 Minimum rate to be charged per the
rate decimals. contract, if a range is specified.
fields
(34, 35,
36, or 37)
must be
included.
36......... Rate Maximum......... One of four Number with up to 4 Maximum rate to be charged per the
rate decimals. contract, if a range is specified.
fields
(34, 35,
36, or 37)
must be
included.
37......... Rate Description..... One of four Unrestricted text.... Text description of rate. If the rate is
rate currently available on the FERC Web
fields site, a citation of the FERC Accession
(34, 35, Number and the relevant FERC tariff
36, or 37) including page number or section may be
must be included instead of providing the
included. 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 See Rate Units Table, Measure stated in the contract for the
specified Appendix F. product sold.
in the
contract.
39......... Point of Receipt If See Balancing The registered NERC Balancing Authority
Balancing Authority specified Authority Table, (formerly called NERC Control Area)
(PORBA). in the Appendix B. where service begins for a transmission
contract. 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.
40......... Point of Receipt If Unrestricted text (50 The specific location at which the
Specific Location specified characters). If product is received if designated in
(PORSL). in the ``HUB'' is selected the contract. If receipt occurs at a
contract. for PORCA, see Hub trading hub, a standardized hub name
Table, Appendix C. 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.
41......... Point of Delivery If See Balancing The registered NERC Balancing Authority
Balancing specified Authority Table, (formerly called NERC Control Area)
Authority(PODBA). in the Appendix B. where a jurisdictional product is
contract. 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.
42......... Point of Delivery If Unrestricted text (50 The specific location at which the
Specific Location specified characters). If product is delivered if designated in
(PODSL). in the ``HUB'' is selected the contract. If receipt occurs at a
contract. for PODCA, see Hub trading hub, a standardized hub name
Table, Appendix C. must be used.
[[Page 12989]]
43......... Begin Date........... If YYYYMMDDHHMM......... First date for the sale of the product
specified at the rate specified.
in the
contract.
44......... End Date............. If YYYYMMDDHHMM......... Last date for the sale of the product at
specified the rate specified.
in the
contract.
45......... Time Zone............ [check] See Time Zone Table, The time zone in which the sales will be
Appendix D. made under the contract.
----------------------------------------------------------------------------------------------------------------
QR Data Dictionary--Transaction Data
----------------------------------------------------------------------------------------------------------------
Field No. Field Required Value Definition
----------------------------------------------------------------------------------------------------------------
46.............. Transaction Unique ID [check] An integer proceeded An identifier beginning
by the letter ``T'' with the letter ``T''
(only used when and followed by a number
importing (e.g., ``T1'', ``T2'')
transaction data). 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.
47.............. Seller Company Name.. [check] Unrestricted text The name of the company
(100 Characters). 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).
48.............. Customer Company Name [check] Unrestricted text (70 The name of the
Characters). counterparty.
49.............. Customer DUNS Number. [check] Nine digit number.... The unique nine digit
number assigned by Dun
and Bradstreet to the
counterparty to the
contract.
50.............. FERC Tariff Reference [check] Unrestricted text (60 The FERC tariff reference
Characters). 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.
51.............. Contract Service [check] Unrestricted text (30 Unique identifier given
Agreement ID. Characters). 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.
52.............. Transaction Unique [check] Unrestricted text (24 Unique reference number
Identifier. Characters). assigned by the seller
