FR Doc E8-26209

[Federal Register: November 4, 2008 (Volume 73, Number 214)]
[Rules and Regulations]
[Page 65526-65541]
From the Federal Register Online via GPO Access [wais.access.gpo.gov]
[DOCID:fr04no08-11]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

18 CFR Part 35

[Docket Nos. RM01-8-009 and RM01-8-010]

Revised Public Utility Filing Requirements for Electric Quarterly
Reports

Issued October 28, 2008.
AGENCY: Federal Energy Regulatory Commission, DOE.

ACTION: Order No. 2001-I; Order Revising Electric Quarterly Report
(EQR) Data Dictionary.

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SUMMARY: In this order, the Federal Energy Regulatory Commission
(Commission) revises the EQR Data Dictionary to define and rename Field
22 of the EQR to ``Commencement Date of Contract Terms'' and to clarify
the information to be reported in the EQR concerning ancillary
services. These revisions will make reporting this information less
burdensome and more accessible.

DATES: Effective Date: This order will become effective upon
publication in the Federal Register. The definitions adopted in this
order shall be used in filing the Q1, 2009 EQR due on April 30, 2009
and in subsequent filings of the EQR.

FOR FURTHER INFORMATION CONTACT:

Mark Blazejowski (Technical Information), Office of Enforcement,
Federal Energy Regulatory Commission, 888 First Street, NE.,
Washington, DC 20426, (202) 502-6055.
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. In this order, after consideration of the comments filed in
response to our notices seeking comment,\1\ we are revising the
Electric Quarterly Report (EQR) Data Dictionary. Specifically, we are
revising the EQR Data Dictionary to define and rename Field 22 of the
EQR to ``Commencement Date of Contract Terms,'' as this field is
intended to be used to identify when the current terms of the reported
contract became effective. This order also clarifies the information to
be reported in the EQR concerning ancillary services.
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\1\ Revised Public Utility Filing Requirements for Electric
Quarterly Reports, 73 FR 12983 (Mar. 11, 2008), FERC Stats. & Regs.
] 35,557 (2008) (EQR Ancillary Services Notice); Revised Public
Utility Filing Requirements for Electric Quarterly Reports, 73 FR
30543 (May 28, 2008), FERC Stats. & Regs. ] 35,558 (2008)
(Commencement Date Notice).
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I. Background

A. EQRs and EQR Data Dictionary

2. On April 25, 2002, the Commission issued Order No. 2001, a final
rule establishing revised public utility filing requirements. This rule
requires public utilities to file EQRs summarizing specified pertinent
data about their currently effective contracts (contract data) and data
about wholesale power sales they made during the reporting period
(transaction data).\2\ 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.
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\2\ Revised Public Utility Filing Requirements, Order No. 2001,
67 FR 31043, FERC Stats. & Regs. ] 31,127 (2002), reh'g denied,
Order No. 2001-A, 100 FERC ] 61,074 (2002), reh'g denied, Order No.
2001-B, 100 FERC ] 61,342 (2002).
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3. In Order No. 2001, the Commission also adopted a new section in
its regulations, 18 CFR 35.10b, which requires that the EQRs are to be
prepared in conformance with the Commission's software and guidance
posted and available from the Commission's Web site. This provision
obviates the need to revise the Commission's regulations to implement
revisions to the EQR 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 on how to report certain transactions.\3\
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\3\ See, e.g., Notice Providing Guidance on the Filing of
Information on Transmission Capacity Reassignments in Electric
Quarterly Reports, 124 FERC ] 61,244 (2008), which provided guidance
on complying with the Commission's Order No. 890-B reporting
requirements; Revised Public Utility Filing Requirements, Order No.
2001-E, 105 FERC ] 61,352 (2003), where the Commission standardized
the terminology for control areas; and Revised Public Utility Filing
Requirements, 67 FR 65973 (Oct. 29, 2002), FERC Stats. & Regs. ]
35,045 (Oct. 21, 2002), which provided general guidance for using
the EQR software.
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4. 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 and
providing formal definitions for fields that were previously undefined.

B. Commencement Date

5. On December 20, 2007, the Commission issued Order No. 2001-H,
which addressed a pending request for rehearing and clarified the
information to be reported in several EQR data fields. In Order No.
2001-H, the Commission defined Field 22 in the Contract Data section of
the EQR, named ``Contract Commencement Date,'' as:

The date the terms of the contract reported in the EQR were
effective. If the terms reported in the Contract Data section of the
EQR became effective or if service under those terms began on
multiple dates (i.e., due to an amendment), the date to be reported
as the Commencement Date is the date when service began pursuant to
the most recent amendment to the terms reported in the Contract Data
section of the EQR.\4\
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\4\ Revised Public Utility Filing Requirements for Electric
Quarterly Reports, Order No. 2001-H, 121 FERC ] 61,289 (2007), Data
Dictionary at Field 22.

6. On February 26, 2008, the Commission held a technical conference
to ``review the EQR Data Dictionary and address questions from EQR
users.'' \5\

[[Page 65527]]

During this technical conference, the participants discussed, among
other matters, whether the Commission intended in Order No. 2001-H for
the commencement date field to be used to report the date the contract
terms reported in the EQR (original or amended) became effective. On
April 17, 2008, in response to participants' requests, the Commission's
Director, Office of Enforcement, issued a waiver, for the first quarter
of 2008, of the requirement to file EQRs using the commencement date
definition as clarified in Order No. 2001-H.\6\ On July 9, 2008, the
waiver was extended until final action is taken in this docket.\7\
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\5\ See Notice of Electric Quarterly Reports Technical
Conference, 73 FR 2477 (Jan. 15, 2008).
\6\ See Edison Electric Institute, Docket Nos. RM01-8-000, RM01-
8-007 and ER02-2001-000 (Apr. 17, 2008) (unpublished letter order).
\7\ See Edison Electric Institute, Docket Nos. RM01-8-000, RM01-
8-007 and ER02-2001-000 (July 9, 2008) (unpublished letter order).
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7. On May 28, 2008, the Commission issued the Commencement Date
Notice to invite comment on the issues raised in the technical
conference. In addition, the Commencement Date Notice proposed defining
commencement date as:

The date the terms of the contract reported in the Contract
Products section of the EQR (Field Nos. 26 through 45) were
effective. If the terms reported in the Contract Data section of the
EQR became effective on multiple dates (i.e., due to one or more
amendments), the date to be reported as the Commencement Date is the
date the most recent amendment became effective. If the contract or
the most recent reported amendment does not have an effective date,
the date when service began pursuant to the contract or most recent
reported amendment may be used. If the terms of the contract
reported in the Contract Products section have not been amended
since January 1, 2008, the initial date the contract became
effective may be used.

8. The Commission also proposed renaming the field to
``Commencement Date of Contract Terms.'' \8\ On April 10, 2008, three
entities filed timely comments on the Commencement Date Notice.\9\
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\8\ As noted above, Field 22 has been previously titled
``Contract Commencement Date.''
\9\ Timely comments on the Commencement Date Notice were filed
by: Edison Electric Institute (EEI); Sempra Energy, Inc. (Sempra);
and Occidental Power Services, Inc. (Occidental).
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C. Ancillary Service Reporting

9. Order No. 888 adopted six ancillary services to be included in
the open access transmission tariff (OATT): 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); and Operating Reserve--Supplemental--or
Supplemental Reserve--(Schedule 6).\10\
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\10\ Promoting Wholesale Competition Through Open Access Non-
discriminatory Transmission Services by Public Utilities; Recovery
of Stranded Costs by Public Utilities and Transmitting Utilities,
Order No. 888, 61 FR 21540 (May 10, 1996), FERC Stats. & Regs. ]
31,036 (1996), order on reh'g, Order No. 888-A, 62 FR 12274 (Mar.
14, 1997), FERC Stats. & Regs. ] 31,048 (1997), order on reh'g,
Order No. 888-B, 81 FERC ] 61,248 (1997), order on reh'g, Order No.
888-C, 82 FERC ] 61,046 (1998), aff'd in relevant part sub nom.
Transmission Access Policy Study Group v. FERC, 225 F.3d 667 (D.C.
Cir. 2000) (TAPS v. FERC), aff'd sub nom. New York v. FERC, 535 U.S.
1 (2002).
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10. The six ancillary services established in Order No. 888 are now
offered under the Order No. 890 pro forma OATT. In Order No. 890, the
Commission also adopted ``generator imbalance'' as a new ancillary
service.\11\
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\11\ 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 (2007), order on reh'g, Order
No. 890-A, 73 FR 2984 (Jan. 16, 2008), FERC Stats. and Regs. ]
31,261 (2007), order on reh'g, Order No. 890-B, 123 FERC ] 61,299
(2008).
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11. On June 21, 2007, the Commission issued Order No. 697, a Final
Rule that codified and, in certain respects, revised the Commission's
standards for market-based rate authority for sales of electric energy,
capacity, and ancillary services.\12\ Among other matters, Order No.
697 addressed the posting and reporting requirements for third-party
sellers of ancillary services at market-based rates.
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\12\ 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 (2007),
clarifying order, 121 FERC ] 61,260 (2007), order on reh'g, Order
No. 697-A, 73 FR 25,832 (May 7, 2008), FERC Stats. & Regs. ] 31,268
(2008).
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12. The matter of third-party sellers of ancillary services at
market-based rates had previously been addressed in Avista Corporation,
87 FERC ] 61,223, order on reh'g, 89 FERC ] 61,136 (1999) (Avista),
among other cases. Avista provided a policy 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, under certain
conditions. The authorization in Avista extended only to the following
four ancillary services: Regulation Service; Energy Imbalance Service;
Spinning Reserves; and Supplemental Reserves.
13. On March 3, 2008, the Commission issued the EQR Ancillary
Services Notice to clarify the requirement to report third-party
ancillary service transactions. The notice proposed adding the phrase
``Reported for power sales and transmission-related transactions'' to
clarify the EQR reporting requirements with regard to Energy Imbalance,
Regulation & Frequency Response, Spinning Reserve, and Supplemental
Reserve--the four products identified in Avista--``to clarify that
sales of these services must be reported both in the Contract and
Transaction sections of the EQR.'' The notice also proposed to add
Generator Imbalance as a Product Name in the EQR.\13\ On June 27, 2008,
three entities filed comments in response to the EQR Ancillary Services
Notice.\14\
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\13\ EQR Ancillary Services Notice, FERC Stats. & Regs. ] 35,557
at P 12.
\14\ Timely comments on the EQR Ancillary Services Notice were
filed by: EEI; California Independent System Operator Corporation
(CAISO); and PJM Interconnection, L.L.C. (PJM).
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II. Discussion

A. Commencement Date

1. Comments
14. CAISO states that it supports the intent of the proposed
clarification of the definition of the ``Contract Commencement Date''
in the EQR Data Dictionary and the proposal to rename that EQR field as
``Commencement Date of Contract Terms.'' However, CAISO is concerned
that the proposed commencement date definition (Field 22) is confusing
because it refers to ``the Contract Data section of the EQR'' in the
second sentence and ``the Contract Products section'' elsewhere.\15\
CAISO recommends that the Commission only require that entries to Field
22 be changed as a result of matters affecting the Contract Products
section of the contract data and not based on any other revisions to a
contract. CAISO argues that other information included in the EQR has
no substantive effect on Field 22. CAISO also suggests that, rather
than referring to the ``Commencement Date,'' the definition should
refer specifically to ``Commencement Date of Contract Terms.''
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\15\ EQR filers summarize their contracts in the Contract Data
section of the EQR: Fields 14 through 45. Fields 14 through 20 of
the Contract Data section capture the seller/customer identification
information and fields 21 through 25 capture relevant contract dates
such as commencement and termination dates. The Contract Products
section (Fields 26 through 45) is a subset of the Contract Data
section describing the various offerings under the contract such as
firm and non-firm, long-term, short-term.
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15. EEI's comments generally support the proposed modification.
EEI, however, requests that the Commission modify the definition to
make clear that if the terms of the contract reported in the Contract
Products section have not been amended since January 1, 2008, the filer
may, at its election, use the initial date the contract became
effective (or absent an effective date the initial

[[Page 65528]]

date when service began) as the contract commencement date, even if the
terms of the contract reported in the Contract Products section were
amended prior to January 1, 2008.
16. PJM states that the proposed commencement date definition seems
to raise the possibility that an EQR filer may begin reporting a
contract upon its effective date. PJM raises the concern that this
conflicts with the statement in Order No. 2001 that ``the requirement
to file contract data and transaction data begins with the first
Electric Quarterly Report filed after service commences under an
agreement.'' \16\ PJM asks that the Commission ``permit public
utilities to report agreements in their EQRs upon their effective dates
* * * rather than when service is taken under the agreements.''
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\16\ Order No. 2001, FERC Stats. & Regs. ] 31,127 at P 216.
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2. Commission Determination
17. With regard to CAISO's comments regarding which revisions to
contract terms necessitate changes to the date reported in the
commencement date field, we note that, in Order No. 2001-H, the
Commission stated:

There is a very real public interest in identifying when key
terms of the contract were determined. As market conditions change
over time, it is imperative to be able to sort the deals that
occurred years ago from those that were confirmed more recently. To
better understand the market conditions at the time a contract was
put in place, it is necessary to document the date that key terms
were established.\17\
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\17\ Order No. 2001-H, 121 FERC ] 61,289 at P 12.

18. As discussed below, based on our consideration of the comments,
the Commission concludes that additional specificity is needed to
provide clarity. As an initial matter, we adopt the NOPR's proposal to
change the name of Field 22 to ``Commencement Date of Contract Terms.''
We note that several commenters filed comments supporting such a
change, and no comment was filed that raised objections to this
proposal.
19. In addition, as discussed below, we are also revising the
definition of Field 22 to clearly delineate the contractual changes
that would require a change in the date reported.
20. With regard to EEI's comments, we agree with the suggestion
regarding pre-2008 amendments. In particular, EEI suggests we add the
phrase ``or absent an effective date the initial date when service
began.'' We find this additional phrase further clarifies that the
Commission does not intend to require filers to research contract
histories to comply with its requirements for this field and,
accordingly, we will adopt this proposal.
21. Second, we reject EEI's suggestion that we add the phrase ``the
Filer at its election may use'' because we find that such a phrase
would result in greater ambiguity, rather than clarity, by offering a
range of options on what may be reported rather than requiring a
standard by which all filers must comply. Further, the notion of
inconsistent filings is contrary to the intention of the EQR Data
Dictionary, which was created to reduce the range of possible
interpretations for appropriate entries in the EQR. Such allowable
disparities make the data less uniform and less useful.
22. Finally, we reject the EEI suggestion to add the phrase, ``even
if the terms of the contract reported in the Contract Products section
were amended prior to January 1, 2008'' because we find it redundant
and subject to conflicting interpretations.
23. Accordingly, we rename Field 22 in the EQR as ``Commencement
Date of Contract Terms.'' The field is defined as:

The date the terms of the contract reported in fields 18, 23 and
25 through 45 (as defined in the data dictionary) became effective.
If those terms became effective on multiple dates (i.e., due to one
or more amendments), the date to be reported in this field is the
date the most recent amendment became effective. If the contract or
the most recent reported amendment does not have an effective date,
the date when service began pursuant to the contract or most recent
reported amendment may be used. If the terms reported in fields 18,
23 and 25 through 45 have not been amended since January 1, 2009,
the initial date the contract became effective (or absent an
effective date the initial date when service began) may be used.

24. This definition will become effective on January 1, 2009 and
will be applicable for EQRs filed beginning in the first quarter of
2009. The start date for the reporting of contract amendments has been
changed in the definition to January 1, 2009, to account for the
effective date of the revised EQR Data Dictionary that we are adopting
in this order. The limited waiver for compliance that the Commission
granted on April 17, 2008 and extended on July 9, 2008 will apply to
all 2008 EQRs.\18\
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\18\ The expiration date of the limited waiver also applies to
the Increment Name fields (Fields 28 and 60), for which additional
time was provided to comply with Order No. 2001-G.
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25. PJM is incorrect in its interpretation that the proposed
commencement date definition raises the possibility that an EQR filer
may begin reporting a contract upon its effective date. The
commencement date definition specifies which date should be used to
populate the field and does not otherwise address when a contract must
first be reported in the EQR. The Commission recognizes that,
logistically, it may be more convenient to begin reporting a contract
upon execution. Although the requirement to file a contract in the EQR
once service under that contract commences will remain in effect, the
Commission neither prohibits nor discourages the earlier reporting of
contracts.

B. Ancillary Service Reporting

1. Comments
26. With regard to third-party ancillary service transactions, the
EQR Ancillary Services Notice proposed to add to the phrase ``Reported
for power sales and transmission-related transactions'' to clarify the
EQR reporting requirements with regard to Energy Imbalance, Regulation
& Frequency Response, Spinning Reserve, and Supplemental Reserve in
Appendix A (Product Names) to the EQR Data Dictionary. The notice also
proposed to add the product ``Generator Imbalance'' in the Appendix.
27. In response to this notice, EEI filed comments arguing that
ancillary services associated with transmission contracts should not be
reported in the EQR. Thus, EEI suggests that the reporting requirements
regarding Energy Imbalance, Regulation & Frequency Response, Spinning
Reserve, and Supplemental Reserve be changed to read as follows: ``For
Contracts, reported if the contract provides for sale of the product.
For Transactions, sales by third-party providers (i.e., non-
transmission function) are reported.'' EEI argues that its proposed
language is superior to that proposed by the Commission, because the
language proposed in the EQR Ancillary Services Notice may cause
confusion over whether transmission-related agreements are to be
reported in the EQR. EEI states that ``the Commission has never
required transmission functions to report ancillary service sales in
the Transactions portion of the EQR, which was established in Order No.
2001,'' and ``the suggested changes to the Appendix A definitions may
not clearly enough reflect this existing policy.''
28. EEI also states that ``the definition for Energy Imbalance and
the proposed definition for Generator Imbalance do not indicate that
they may be Ancillary Services'' and asks ``the Commission to clarify
that Energy Imbalance and Generator Imbalance can be an [sic] Ancillary
Services, and that * * *

[[Page 65529]]

[o]nly ancillary services provided by a marketer are reportable
transactions, though both marketers and transmission functions must
list them in the Contracts section of the EQR.''
2. Commission Determination
29. Order No. 2001 stated:

We clarify that ancillary service transaction data associated
with transmission need not be reported when the transmission
services are provided on an unbundled basis * * * On the other hand,
ancillary service transaction data associated with power sales are
currently required to be filed in Quarterly Transaction Reports and
the requirement to file these data is retained in this rule.\19\
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\19\ Order No. 2001 at P 271.

30. Our proposal in the EQR Ancillary Services Notice was intended
to provide clarification regarding the EQR reporting requirements for
ancillary services provided in association with unbundled sales of
transmission services rather than to change the policy (quoted
immediately above) that we established in Order No. 2001.\20\
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\20\ Order No. 697, FERC Stats. & Regs. ] 31,252 at P 1058.
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31. Accordingly, with regard to EEI's suggested changes to the
reporting requirements for Energy Imbalance, Regulation & Frequency
Response, Spinning Reserve, and Supplemental Reserve, the Commission
finds that EEI's proposal provides additional clarity and we therefore
adopt EEI's proposal.
32. Specifically, we revise the ancillary service Product Names as
follows:
Energy Imbalance: Service provided when a difference occurs between
the scheduled and the actual delivery of energy to a load obligation
(Ancillary Service). For Contracts, reported if the contract provides
for sale of the product. For Transactions, sales by third-party
providers (i.e., non-transmission function) are reported.
Generator Imbalance: 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 (Ancillary Service). For
Contracts, reported if the contract provides for sale of the product.
For Transactions, sales by third-party providers (i.e., non-
transmission function) are reported.
Regulation & Frequency Response: 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). For
Contracts, reported if the contract provides for sale of the product.
For Transactions, sales by third-party providers (i.e., non-
transmission function) are reported.
Spinning Reserve: 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). For Contracts, reported if
the contract provides for sale of the product. For Transactions, sales
by third-party providers (i.e., non-transmission function) are
reported.
Supplemental Reserve: 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). For Contracts, reported if the contract provides
for sale of the product. For Transactions, sales by third-party
providers (i.e., non-transmission function) are reported.

C. Reporting of Ancillary Service Product Type Names

1. Comments
33. EEI asks the Commission to ``clarify the appropriate manner to
report the Product Type Name [Field No. 30] for ancillary service sales
in the Contracts portion of the EQR,'' namely, that an ancillary
service ``reported by a transmission function'' should be identified
with a Product Type Name of ``T,'' indicating the product was sold
under a FERC-approved transmission tariff. Alternatively, a merchant
sale would be reported as sold under a FERC-approved cost-based tariff
by entering ``CB'' or market-based tariff by entering ``MB'' as
``factual circumstances dictate.''
34. Occidental seeks clarification ``that imbalances that are
settled in the real-time markets operated by the ISOs and RTOs are not
intended to be reported as `Generator Imbalances' under the proposed
revisions to the EQR Data Dictionary.'' Occidental states that
``imbalances that are settled within the organized markets [are]
handled through the settlement process, in which the generator pays the
real-time price for any under production and is paid the real-time
price for any over production [and] should not be reported in the EQRs
as `Generator Imbalances' under this [FERC-proposed] definition.''
2. Commission Determination
35. Regarding EEI's request for clarification, if the transmission
provider (i.e., non-merchant function) makes an ancillary service sale,
the product type is ``T.'' With respect to third-party sales, the
product type is listed as ``CB,'' if the third-party sale is made under
a cost-based rate tariff or ``MB,'' if the third-party sale is made
under a market-based rate tariff. We believe that Product Type Name
[Field No. 30] adequately addresses this distinction and, thus, do not
find any reason to revise the ancillary service reporting requirements
that we proposed in the EQR Ancillary Services Notice to add clarity on
this issue.
36. In addition, we find that Occidental is correct in its
interpretation of the difference between energy imbalance service
offered as an ancillary service in general and the method by which
organized markets address imbalances through settlement in the Real-
Time market. The Commission has adopted conventions for reporting
trading within Real-Time markets.\21\ This order does not change those
conventions.
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\21\ Revised Public Utility Filing Requirements for Electric
Quarterly Reports, Order No. 2001-G, 120 FERC ] 61,270, at P 55
(2007).
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D. Whether Ancillary Services Not Included in the OATT Should Be
Reported in EQRs

1. Comments
37. The EQR Ancillary Services Notice invited comment on the need
to include additional non-OATT ancillary services in the list of
Product Names in the EQR Data Dictionary. Two commenters filed comments
addressing this issue. EEI states that it ``recommends against
including any other ancillary services in the EQR at this time.''
38. Sempra comments that ``the industry may benefit from additional
clarification with respect to the reporting of ISO/RTO-specific
ancillary services that may not be currently reflected'' in the OATT.
Sempra also suggests that there are benefits to clarifying ``the
reporting of other ISO/RTO-specific products.'' To this end, Sempra
asks that the Commission clarify ``the appropriate reporting `bucket'
for other CAISO products, such

[[Page 65530]]

as Instructed Imbalance Energy and Uninstructed Imbalance Energy.'' As
to whether the Commission should add specific new ancillary services to
the EQR Data Dictionary, Sempra asks that the Commission ``consider
whether any additional CAISO products or ancillary services should be
included in the EQR Data Dictionary once the CAISO MRTU [Market
Redesign and Technology Upgrade] program is put into effect.'' \22\
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\22\ We note that, while Sempra asks the Commission to consider
these matters, it does not explicitly advocate that the Commission
add any additional products to the EQR Data Dictionary.
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2. Commission Determination
39. The Commission will continue its policy of identifying only the
standard OATT ancillary services as ancillary services in the Product
Name field of the EQR. This policy is consistent with the Commission's
intention, in establishing the EQR filing requirements, that the same
kinds of information be reported by all EQR filers, in the same format
and using the same definitions. This approach is intended to allow EQR
users and Commission staff to readily compare and contrast the
transactions and contracts reported by one utility to those of other
utilities. We will continue to add products that reflect common and new
offerings by the industry where it appears that these products are
widely offered, but, in this case, we agree with EEI that the current
list of ancillary service product names to be reported in the EQR is
sufficient.
40. As to Sempra's comments about providing clarification regarding
the appropriate reporting of the specific products offered by CAISO, in
Order No. 2001-E, the Commission encouraged RTOs and ISOs to work with
Commission staff to develop EQR-ready reports to ease the filing
process for respondents and to improve consistency in reporting within
and among the organized markets.\23\ Three ISOs--New York ISO, Midwest
ISO and ISO New England--currently provide reports to their members
that format settlement data for the EQR. PJM expects to begin doing so
by the end of 2008.
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\23\ Order No. 2001-E, 105 FERC ] 61,352 at P 11.
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41. In addition, we note that CAISO's staff met with Commission
staff and market participants on May 18, 2004 to map the CAISO's
products to the EQR product list.\24\ Likewise, we encourage CAISO to
meet with Commission staff on MRTU product mapping and provide EQR-
ready reports to ease the filing process for respondents.
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\24\ Notice of Electric Quarterly Reports Western Outreach
Session, 69 FR 25897 (May 10, 2004). The mapping developed in this
meeting is available on the Commission's Web site (http://
www.ferc.gov/EventCalendar/
EventDetails.aspx?ID=1096&CalType=%20&Date=5/18/
2004&CalendarID=116).
---------------------------------------------------------------------------

III. Document Availability

42. 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 (http://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.
43. From the Commission's Home Page on the Internet, this
information is available in the eLibrary. The full text of this
document is available in the eLibrary both in PDF and Microsoft Word
format for viewing, printing, and/or downloading. To access this
document in eLibrary, type ``RM01-8'' in the docket number field. User
assistance is available for eLibrary and the Commission's Web site
during the Commission's normal business hours. For assistance contact
the Commission's Online Support services at FERCOnlineSupport@ferc.gov
or toll-free at (866) 208-3676, or for TTY, contact (202) 502-8659.
The Commission orders:
(A) The Commission hereby adopts the changes in the EQR Data
Dictionary shown in the Attachment, as discussed in the body of this
order.
(B) This order will become effective upon publication in the
Federal Register. The definitions adopted in this order shall be used
in filing the Q1, 2009 EQR due on April 30, 2009 and in subsequent
filings of the EQR.
(C) The limited waiver for compliance granted on April 17, 2008 and
extended on July 9, 2008 will apply to all 2008 EQRs and only to 2008
EQRs, regardless of when they are filed.

By the Commission.
Kimberly D. Bose,
Secretary.

Attachment

Electric Quarterly Report Data Dictionary Version 1.1 (Issued October
28, 2008)

EQR Data Dictionary
----------------------------------------------------------------------------------------------------------------
Field No. Field Required Value Definition
----------------------------------------------------------------------------------------------------------------
ID Data
----------------------------------------------------------------------------------------------------------------
1.................. Filer Unique X.................... 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 X.................... FS (where (Seller)--An identifier
Identifier. ``'' is an (e.g., ``FS1'',
integer). ``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.
1.................. Filer Unique X.................... 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........ X.................... Unrestricted text (Respondent)--The name
(100 characters). of the company taking
responsibility for
complying with the
Commission's
regulations related to
the EQR.

[[Page 65531]]

2.................. Company Name........ X.................... Unrestricted text (Seller)--The name of
(100 characters). 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.
2.................. Company Name........ X.................... 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........ X.................... Unrestricted text (Respondent)--Name of
(50 characters). the person at the
Respondent's company
taking responsibility
for compliance with the
Commission's EQR
regulations.
4.................. Contact Name........ X.................... Unrestricted text (Seller)--The name of
(50 characters). 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.
4.................. Contact Name........ X.................... Unrestricted text (Agent)--Name of the
(50 characters). contact for the Agent,
usually the person who
prepares the filing.
5.................. Contact Title....... X.................... Unrestricted text Title of contact
(50 characters). identified in Field
Number 4.
6.................. Contact Address..... X.................... Unrestricted text... Street address for
contact identified in
Field Number 4.
7.................. Contact City........ X.................... Unrestricted text City for the contact
(30 characters). identified in Field
Number 4.
8.................. Contact State....... X.................... Unrestricted text (2 Two character state or
characters). province abbreviations
for the contact
identified in Field
Number 4.
9.................. Contact Zip......... X.................... Unrestricted text Zip code for the contact
(10 characters) CA-- identified in Field
Canada, MX--Mexico. Number 4.
10................. Contact Country Name X.................... US--United States, Country (USA, Canada,
UK--United Kingdom. Mexico, or United
Kingdom) for contact
address identified in
Field Number 4.
11................. Contact Phone....... X.................... Unrestricted text Phone number of contact
(20 characters). identified in Field
Number 4.
12................. Contact E-Mail...... X.................... Unrestricted text... E-mail address of
contact identified in
Field Number 4.
13................. Filing Quarter...... X.................... YYYYMM.............. A six digit reference
number used by the EQR
software to indicate
the quarter and year of
the filing for the
purpose of importing
data from csv files.
The first 4 numbers
represent the year
(e.g., 2007). The last
2 numbers represent the
last month of the
quarter (e.g., 03 = 1st
quarter; 06 = 2nd
quarter, 09 = 3rd
quarter, 12 = 4th
quarter).
----------------------------------------------------------------------------------------------------------------
Contract Data
----------------------------------------------------------------------------------------------------------------
14................. Contract Unique ID.. X.................... An integer preceded An identifier beginning
by the letter ``C'' with the letter ``C''
(only used when and followed by a
importing contract number (e.g., ``C1'',
data). ``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.
15................. Seller Company Name. X.................... 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 Number 2 of the
ID Data (Seller Data).
16................. Customer Company X.................... Unrestricted text The name of the
Name. (70 characters). counterparty.
17................. Customer DUNS Number X.................... Nine digit number... The unique nine digit
number assigned by Dun
and Bradstreet to the
company identified in
Field Number 16.
18................. Contract Affiliate.. X.................... Y (Yes), N (No)..... 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.

[[Page 65532]]

19................. FERC Tariff X.................... Unrestricted text The FERC tariff
Reference. (60 characters). reference cites the
document that specifies
the terms and
conditions under which
a Seller is authorized
to make transmission
sales, power sales or
sales of related
jurisdictional services
at cost-based rates or
at market-based rates.
If the sales are market-
based, the tariff that
is specified in the
FERC order granting the
Seller Market Based
Rate Authority must be
listed.
20................. Contract Service X.................... Unrestricted text Unique identifier given
Agreement ID. (30 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 with and
accepted by the
Commission, or it may
be generated as part of
an internal
identification system.
21................. Contract Execution X.................... YYYYMMDD............ The date the contract
Date. was signed. If the
parties signed on
different dates, use
the most recent date
signed.
22................. Commencement Date of X.................... YYYYMMDD............ The date the terms of
Contract Terms. the contract reported
in fields 18, 23 and 25
through 45 (as defined
in the data dictionary)
became effective. If
those terms became
effective on multiple
dates (i.e.: due to one
or more amendments),
the date to be reported
in this field is the
date the most recent
amendment became
effective. If the
contract or the most
recent reported
amendment does not have
an effective date, the
date when service began
pursuant to the
contract or most recent
reported amendment may
be used. If the terms
reported in fields 18,
23 and 25 through 45
have not been amended
since January 1, 2009,
the initial date the
contract became
effective (or absent an
effective date the
initial date when
service began) may be
used.
23................. Contract Termination If specified in the YYYYMMDD............ The date that the
Date. contract. contract expires.
24................. Actual Termination If contract YYYYMMDD............ The date the contract
Date. terminated. actually terminates.
25................. Extension Provision X.................... Unrestricted text... Description of terms
Description. that provide for the
continuation of the
contract.
26................. Class Name.......... X.................... .................... See definitions of each
class name below.
26................. Class Name.......... X.................... 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.......... X.................... 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.......... X.................... UP--Unit Power Sale. Designates a dedicated
sale of energy and
capacity from one or
more than one specified
generation unit(s).
26................. Class Name.......... X.................... N/A--Not Applicable. To be used only when the
other available Class
Names do not apply.
27................. Term Name........... X.................... LT--Long Term, ST-- Contracts with durations
Short Term, N/A-- of one year or greater
Not Applicable. are long-term.
Contracts with shorter
durations are short-
term.
28................. Increment Name...... X.................... .................... See definitions for each
increment below.
28................. Increment Name...... X.................... 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...... X.................... 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...... X.................... 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).

[[Page 65533]]

28................. Increment Name...... X.................... 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...... X.................... Y--Yearly........... Terms of the contract
(if specifically noted
in the contract) set
for one year or more
(>= 1 year).
28................. Increment Name...... X.................... N/A--Not Applicable. Terms of the contract do
not specify an
increment.
29................. Increment Peaking X.................... .................... See definitions for each
Name. increment peaking name
below.
29................. Increment Peaking X.................... FP--Full Period..... The product described
Name. may be sold during
those hours designated
as on-peak and off-peak
in the NERC region of
the point of delivery.
29................. Increment Peaking X.................... OP--Off-Peak........ The product described
Name. may be sold only during
those hours designated
as off-peak in the NERC
region of the point of
delivery.
29................. Increment Peaking X.................... P--Peak............. The product described
Name. may be sold only during
those hours designated
as on-peak in the NERC
region of the point of
delivery.
29................. Increment Peaking X.................... N/A--Not Applicable. To be used only when the
Name. increment peaking name
is not specified in the
contract.
30................. Product Type Name... X.................... .................... See definitions for each
product type below.
30................. Product Type Name... X.................... CB--Cost Based...... Energy or capacity sold
under a FERC-approved
cost-based rate tariff.
30................. Product Type Name... X.................... CR--Capacity An agreement under which
Reassignment. a transmission provider
sells, assigns or
transfers all or
portion of its rights
to an eligible
customer.
30................. Product Type Name... X.................... MB--Market Based.... Energy or capacity sold
under the seller's FERC-
approved market-based
rate tariff.
30................. Product Type Name... X.................... T--Transmission..... The product is sold
under a FERC-approved
transmission tariff.
30................. Product Type Name... X.................... Other............... The product cannot be
characterized by the
other product type
names.
31................. Product Name........ X.................... See Product Name Description of product
Table, Appendix A. being offered.
32................. Quantity............ If specified in the Number with up to 4 Quantity for the
contract. decimals. contract product
identified.
33................. Units............... If specified in the See Units Table, Measure stated in the
contract. Appendix E. contract for the
product sold.
34................. Rate................ One of four rate Number with up to 4 The charge for the
fields (34, 35, 36, decimals. product per unit as
or 37) must be stated in the contract.
included.
35................. Rate Minimum........ One of four rate Number with up to 4 Minimum rate to be
fields (34, 35, 36, decimals. charged per the
or 37) must be contract, if a range is
included. specified.
36................. Rate Maximum........ One of four rate Number with up to 4 Maximum rate to be
fields (34, 35, 36, decimals. charged per the
or 37) must be contract, if a range is
included. specified.

[[Page 65534]]

37................. Rate Description.... One of four rate Unrestricted text... Text description of
fields (34, 35, 36, rate. If the rate is
or 37) must be currently available on
included. the FERC Web site, a
citation of the FERC
Accession Number and
the relevant FERC
tariff including page
number or section may
be included instead of
providing the entire
rate algorithm. If the
rate is not available
on the FERC Web site,
include the rate
algorithm, if rate is
calculated. If the
algorithm would exceed
the 150 character field
limit, it may be
provided in a
descriptive summary
(including bases and
methods of
calculations) with a
detailed citation of
the relevant FERC
tariff including page
number and section. If
more than 150
characters are
required, the contract
product may be repeated
in a subsequent line of
data until the rate is
adequately described.
38................. Rate Units.......... If specified in the See Rate Units Measure stated in the
contract. Table, Appendix F. contract for the
product sold.
39................. Point of Receipt If specified in the See Balancing The registered NERC
Balancing Authority contract. Authority Table, Balancing Authority
(PORBA). Appendix B. (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.
40................. Point of Receipt If specified in the Unrestricted text The specific location at
Specific Location contract. (50 characters). If which the product is
(PORSL). ``HUB'' is selected received if designated
for PORCA, see Hub in the contract. If
Table, Appendix C. 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.
41................. Point of Delivery If specified in the See Balancing The registered NERC
Balancing Authority contract. Authority Table, Balancing Authority
(PODBA). Appendix B. (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.
42................. Point of Delivery If specified in the Unrestricted text The specific location at
Specific Location contract. (50 characters). If which the product is
(PODSL). ``HUB'' is selected delivered if designated
for PODCA, see Hub in the contract. If
Table, Appendix C. receipt occurs at a
trading hub, a
standardized hub name
must be used.
43................. Begin Date.......... If specified in the YYYYMMDDHHMM........ First date for the sale
contract. of the product at the
rate specified.
44................. End Date............ If specified in the YYYYMMDDHHMM........ Last date for the sale
contract. of the product at the
rate specified.
45................. Time Zone........... X.................... See Time Zone Table, The time zone in which
Appendix D. the sales will be made
under the contract.
----------------------------------------------------------------------------------------------------------------
Transaction Data
----------------------------------------------------------------------------------------------------------------
46................. Transaction Unique X.................... An integer preceded An identifier beginning
ID. by the letter ``T'' with the letter ``T''
(only used when and followed by a
importing number (e.g., ``T1'',
transaction data). ``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.

[[Page 65535]]

47................. Seller Company Name. X.................... 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 X.................... Unrestricted text The name of the
Name. (70 Characters). counterparty.
49................. Customer DUNS Number X.................... Nine digit number... The unique nine digit
number assigned by Dun
and Bradstreet to the
counterparty to the
contract.
50................. FERC Tariff X.................... Unrestricted text The FERC tariff
Reference. (60 Characters). reference cites the
document that specifies
the terms and
conditions under which
a Seller is authorized
to make transmission
sales, power sales or
sales of related
jurisdictional services
at cost-based rates or
at market-based rates.
If the sales are market-
based, the tariff that
is specified in the
FERC order granting the
Seller Market Based
Rate Authority must be
listed.
51................. Contract Service X.................... Unrestricted text Unique identifier given
Agreement ID. (30 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 X.................... Unrestricted text Unique reference number
Identifier. (24 Characters). assigned by the seller
for each transaction.
53................. Transaction Begin X.................... YYYYMMDDHHMM (csv First date and time the
Date. import), product is sold during
MMDDYYYYHHMM the quarter.
(manual entry).
54................. Transaction End Date X.................... YYYYMMDDHHMM (csv Last date and time the
import), product is sold during
MMDDYYYYHHMM the quarter.
(manual entry).
55................. Time Zone........... X.................... See Time Zone Table, The time zone in which
Appendix D. the sales will be made
under the contract.
56................. Point of Delivery X.................... See Balancing The registered NERC
Balancing Authority Authority Table, Balancing Authority
(PODBA). Appendix B. (formerly called NERC
Control Area)
abbreviation used in
OASIS applications.
57................. Point of Delivery X.................... Unrestricted text The specific location at
Specific Location (50 characters). If which the product is
(PODSL). ``HUB'' is selected delivered. If receipt
for PODBA, see Hub occurs at a trading
Table, Appendix C. hub, a standardized hub
name must be used.
58................. Class Name.......... X.................... .................... See class name
definitions below.
58................. Class Name.......... X.................... F--Firm............. A sale, service or
product that is not
interruptible for
economic reasons.
58................. Class Name.......... X.................... NF--Non-firm........ A sale for which
delivery or receipt of
the energy may be
interrupted for any
reason or no reason,
without liability on
the part of either the
buyer or seller.
58................. Class Name.......... X.................... UP--Unit Power Sale. Designates a dedicated
sale of energy and
capacity from one or
more than one specified
generation unit(s).
58................. Class Name.......... X.................... BA--Billing Designates an
Adjustment. 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.
58................. Class Name.......... X.................... N/A--Not Applicable. To be used only when the
other available class
names do not apply.
59................. Term Name........... X.................... LT--Long Term, ST-- Power sales transactions
Short Term, N/A-- with durations of one
Not Applicable. year or greater are
long-term. Transactions
with shorter durations
are short-term.
60................. Increment Name...... X.................... .................... See increment name
definitions below.
60................. Increment Name...... X.................... H--Hourly........... Terms of the particular
sale set for up to 6
consecutive hours (<= 6
consecutive hours).
Includes LMP based
sales in ISO/RTO
markets.
60................. Increment Name...... X.................... D--Daily............ Terms of the particular
sale set for more than
6 and up to 60
consecutive hours (> 6
and <= 60 consecutive
hours). Includes sales
over a peak or off-peak
block during a single
day.

[[Page 65536]]

60................. Increment Name...... X.................... W--Weekly........... Terms of the particular
sale set for over 60
consecutive hours and
up to 168 consecutive
hours (> 60 and <= 168
consecutive hours).
Includes sales for a
full week and sales for
peak and off-peak
blocks over a
particular week.
60................. Increment Name...... X.................... M--Monthly.......... Terms of the particular
sale set for more than
168 consecutive hours
up to, but not
including, one year (>
168 consecutive hours
and < 1 year). Includes
sales for full month or
multi-week sales during
a given month.
60................. Increment Name...... X.................... Y--Yearly........... 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).
60................. Increment Name...... X.................... N/A--Not Applicable. To be used only when
other available
increment names do not
apply.
61................. Increment Peaking X.................... .................... See definitions for
Name. increment peaking
below.
61................. Increment Peaking X.................... FP--Full Period..... The product described
Name. was sold during Peak
and Off-Peak hours.
61................. Increment Peaking X.................... OP--Off-Peak........ The product described
Name. was sold only during
those hours designated
as off-peak in the NERC
region of the point of
delivery.
61................. Increment Peaking X.................... P--Peak............. The product described
Name. was sold only during
those hours designated
as on-peak in the NERC
region of the point of
delivery.
61................. Increment Peaking X.................... N/A--Not Applicable. To be used only when the
Name. other available
increment peaking names
do not apply.
62................. Product Name........ X.................... See Product Names Description of product
Table, Appendix A. being offered.
63................. Transaction Quantity X.................... Number with up to 4 The quantity of the
decimals. product in this
transaction.
64................. Price............... X.................... Number with up to 6 Actual price charged for
decimals. the product per unit.
The price reported
cannot be averaged or
otherwise aggregated.
65................. Rate Units.......... X.................... See Rate Units Measure appropriate to
Table, Appendix F. the price of the
product sold.
66................. Total Transmission X.................... Number with up to 2 Payments received for
Charge. decimals. transmission services
when explicitly
identified.
67................. Total Transaction X.................... Number with up to 2 Transaction Quantity
Charge. decimals. (Field 63) times Price
(Field 64) plus Total
Transmission Charge
(Field 66).
----------------------------------------------------------------------------------------------------------------

EQR Data Dictionary
[Appendix A. Product Names]
----------------------------------------------------------------------------------------------------------------
Contract Transaction
Product name product product Definition
----------------------------------------------------------------------------------------------------------------
BLACK START SERVICE.................. X X 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).
BOOKED OUT POWER..................... ............... X Energy or capacity contractually
committed bilaterally for delivery but
not actually delivered due to some
offsetting or countervailing trade
(Transaction only).
CAPACITY............................. X X A quantity of demand that is charged on
a $/KW or $/MW basis.
CUSTOMER CHARGE...................... X X Fixed contractual charges assessed on a
per customer basis that could include
billing service.
DIRECT ASSIGNMENT FACILITIES CHARGE.. X ............... Charges for facilities or portions of
facilities that are constructed or
used for the sole use/benefit of a
particular customer.
EMERGENCY ENERGY..................... X ............... Contractual provisions to supply energy
or capacity to another entity during
critical situations.
ENERGY............................... X X A quantity of electricity that is sold
or transmitted over a period of time.
ENERGY IMBALANCE..................... X X Service provided when a difference
occurs between the scheduled and the
actual delivery of energy to a load
obligation (Ancillary Service). For
Contracts, reported if the contract
provides for sale of the product. For
Transactions, sales by third-party
providers (i.e., non-transmission
function) are reported.
EXCHANGE............................. X X 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.
FUEL CHARGE.......................... X X Charge based on the cost or amount of
fuel used for generation.

[[Page 65537]]

GENERATOR IMBALANCE.................. X X 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
(Ancillary Service). For Contracts,
reported if the contract provides for
sale of the product. For Transactions,
sales by third-party providers (i.e.,
non-transmission function) are
reported.
GRANDFATHERED BUNDLED................ X X Services provided for bundled
transmission, ancillary services and
energy under contracts effective prior
to Order No. 888's OATTs.
INTERCONNECTION AGREEMENT............ X ............... 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.
MEMBERSHIP AGREEMENT................. X ............... Agreement to participate and be subject
to rules of a system operator.
MUST RUN AGREEMENT................... X ............... An agreement that requires a unit to
run.
NEGOTIATED-RATE TRANSMISSION......... X X Transmission performed under a
negotiated rate contract (applies only
to merchant transmission companies).
NETWORK.............................. X ............... Transmission service under contract
providing network service.
NETWORK OPERATING AGREEMENT.......... X ............... 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.
OTHER................................ X X Product name not otherwise included.
POINT-TO-POINT AGREEMENT............. X ............... Transmission service under contract
between specified Points of Receipt
and Delivery.
REACTIVE SUPPLY & VOLTAGE CONTROL.... X X Production or absorption of reactive
power to maintain voltage levels on
transmission systems (Ancillary
Service).
REAL POWER TRANSMISSION LOSS......... X X The loss of energy, resulting from
transporting power over a transmission
system.
REGULATION & FREQUENCY RESPONSE...... X X 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). For Contracts,
reported if the contract provides for
sale of the product. For Transactions,
sales by third-party providers (i.e.,
non-transmission function) are
reported.
REQUIREMENTS SERVICE................. X X 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.)
SCHEDULE SYSTEM CONTROL & DISPATCH... X X 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).
SPINNING RESERVE..................... X X 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). For
Contracts, reported if the contract
provides for sale of the product. For
Transactions, sales by third-party
providers (i.e., non-transmission
function) are reported.
SUPPLEMENTAL RESERVE................. X X 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). For Contracts,
reported if the contract provides for
sale of the product. For Transactions,
sales by third-party providers (i.e.,
non-transmission function) are
reported.
SYSTEM OPERATING AGREEMENTS.......... X ............... 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.
TOLLING ENERGY....................... X X Energy sold from a plant whereby the
buyer provides fuel to a generator
(seller) and receives power in return
for pre-established fees.
TRANSMISSION OWNERS AGREEMENT........ X ............... The agreement that establishes the
terms and conditions under which a
transmission owner transfers
operational control over designated
transmission facilities.
UPLIFT............................... X X A make-whole payment by an RTO/ISO to a
utility.
----------------------------------------------------------------------------------------------------------------

[[Page 65538]]

EQR Data Dictionary
[Appendix B. Balancing Authority]
----------------------------------------------------------------------------------------------------------------
Balancing authority Abbreviation Outside US *
----------------------------------------------------------------------------------------------------------------
AESC, LLC--Wheatland CIN........................ AEWC......................................... ...............
Alabama Electric Cooperative, Inc............... AEC.......................................... ...............
Alberta Electric System Operator................ AESO......................................... X
Alliant Energy Corporate Services, LLC--East.... ALTE......................................... ...............
Alliant Energy Corporate Services, LLC--West.... ALTW......................................... ...............
Ameren Transmission............................. AMRN......................................... ...............
Ameren Transmission, Illinois................... AMIL......................................... ...............
Ameren Transmission, Missouri................... AMMO......................................... ...............
American Transmission Systems, Inc.............. FE........................................... ...............
Aquila Networks--Kansas......................... WPEK......................................... ...............
Aquila Networks--Missouri Public Service........ MPS.......................................... ...............
Aquila Networks--West Plains Dispatch........... WPEC......................................... ...............
Arizona Public Service Company.................. AZPS......................................... ...............
Associated Electric Cooperative, Inc............ AECI......................................... ...............
Avista Corp..................................... AVA.......................................... ...............
Batesville Balancing Authority.................. BBA.......................................... ...............
Big Rivers Electric Corp........................ BREC......................................... ...............
Board of Public Utilities....................... KACY......................................... ...............
Bonneville Power Administration Transmission.... BPAT......................................... ...............
British Columbia Transmission Corporation....... BCTC......................................... X
California Independent System Operator.......... CISO......................................... ...............
Carolina Power & Light Company--CPLW............ CPLW......................................... ...............
Carolina Power and Light Company--East.......... CPLE......................................... ...............
Central and Southwest........................... CSWS......................................... ...............
Central Illinois Light Co....................... CILC......................................... ...............
Chelan County PUD............................... CHPD......................................... ...............
Cinergy Corporation............................. CIN.......................................... ...............
City of Homestead............................... HST.......................................... ...............
City of Independence P&L Dept................... INDN......................................... ...............
City of Tallahassee............................. TAL.......................................... ...............
City Water Light & Power........................ CWLP......................................... ...............
Cleco Power LLC................................. CLEC......................................... ...............
Columbia Water & Light.......................... CWLD......................................... ...............
Comision Federal de Electricidad................ CFE.......................................... X
Constellation Energy Control and Dispatch-- PUPP......................................... ...............
Arkansas.
Constellation Energy Control and Dispatch--City BUBA......................................... ...............
of Benton, AR.
Constellation Energy Control and Dispatch--City DERS......................................... ...............
of Ruston, LA.
Constellation Energy Control and Dispatch-- CNWY......................................... ...............
Conway, Arkansas.
Constellation Energy Control and Dispatch--Gila GRMA......................................... ...............
River.
Constellation Energy Control and Dispatch-- HGMA......................................... ...............
Harquehala.
Constellation Energy Control and Dispatch--North DENL......................................... ...............
Little Rock, AK.
Constellation Energy Control and Dispatch--West WMUC......................................... ...............
Memphis, Arkansas.
Dairyland Power Cooperative..................... DPC.......................................... ...............
DECA, LLC--Arlington Valley..................... DEAA......................................... ...............
Duke Energy Corporation......................... DUK.......................................... ...............
East Kentucky Power Cooperative, Inc............ EKPC......................................... ...............
El Paso Electric................................ EPE.......................................... ...............
Electric Energy, Inc............................ EEI.......................................... ...............
Empire District Electric Co., The............... EDE.......................................... ...............
Entergy......................................... EES.......................................... ...............
ERCOT ISO....................................... ERCO......................................... ...............
Florida Municipal Power Pool.................... FMPP......................................... ...............
Florida Power & Light........................... FPL.......................................... ...............
Florida Power Corporation....................... FPC.......................................... ...............
Gainesville Regional Utilities.................. GVL.......................................... ...............
Georgia System Operations Corporation........... GSOC......................................... ...............
Georgia Transmission Corporation................ GTC.......................................... ...............
Grand River Dam Authority....................... GRDA......................................... ...............
Grant County PUD No. 2.......................... GCPD......................................... ...............
Great River Energy.............................. GRE.......................................... ...............
Great River Energy.............................. GREC......................................... ...............
Great River Energy.............................. GREN......................................... ...............
Great River Energy.............................. GRES......................................... ...............
GridAmerica..................................... GA........................................... ...............
Hoosier Energy.................................. HE........................................... ...............
Hydro-Quebec, TransEnergie...................... HQT.......................................... X
Idaho Power Company............................. IPCO......................................... ...............
Illinois Power Co............................... IP........................................... ...............
Illinois Power Co............................... IPRV......................................... ...............
Imperial Irrigation District.................... IID.......................................... ...............
Indianapolis Power & Light Company.............. IPL.......................................... ...............

[[Page 65539]]

ISO New England Inc............................. ISNE......................................... ...............
JEA............................................. JEA.......................................... ...............
Kansas City Power & Light Co.................... KCPL......................................... ...............
Lafayette Utilities System...................... LAFA......................................... ...............
LG&E Energy Transmission Services............... LGEE......................................... ...............
Lincoln Electric System......................... LES.......................................... ...............
Los Angeles Department of Water and Power....... LDWP......................................... ...............
Louisiana Energy & Power Authority.............. LEPA......................................... ...............
Louisiana Generating, LLC....................... LAGN......................................... ...............
Madison Gas and Electric Company................ MGE.......................................... ...............
Manitoba Hydro Electric Board, Transmission MHEB......................................... X
Services.
Michigan Electric Coordinated System............ MECS......................................... ...............
Michigan Electric Coordinated System--CONS...... CONS......................................... ...............
Michigan Electric Coordinated System--DECO...... DECO......................................... ...............
MidAmerican Energy Company...................... MEC.......................................... ...............
Midwest ISO..................................... MISO......................................... ...............
Minnesota Power, Inc............................ MP........................................... ...............
Montana-Dakota Utilities Co..................... MDU.......................................... ...............
Muscatine Power and Water....................... MPW.......................................... ...............
Nebraska Public Power District.................. NPPD......................................... ...............
Nevada Power Company............................ NEVP......................................... ...............
New Brunswick Power Corporation................. NBPC......................................... X
New Horizons Electric Cooperative............... NHC1......................................... ...............
New York Independent System Operator............ NYIS......................................... ...............
North American Electric Reliability Council..... TEST......................................... ...............
Northern Indiana Public Service Company......... NIPS......................................... ...............
Northern States Power Company................... NSP.......................................... ...............
NorthWestern Energy............................. NWMT......................................... ...............
Ohio Valley Electric Corporation................ OVEC......................................... ...............
Oklahoma Gas and Electric....................... OKGE......................................... ...............
Ontario--Independent Electricity Market Operator IMO.......................................... X
OPPD CA/TP...................................... OPPD......................................... ...............
Otter Tail Power Company........................ OTP.......................................... ...............
P.U.D. No. 1 of Douglas County.................. DOPD......................................... ...............
PacifiCorp-East................................. PACE......................................... ...............
PacifiCorp-West................................. PACW......................................... ...............
PJM Interconnection............................. PJM.......................................... ...............
Portland General Electric....................... PGE.......................................... ...............
Public Service Company of Colorado.............. PSCO......................................... ...............
Public Service Company of New Mexico............ PNM.......................................... ...............
Puget Sound Energy Transmission................. PSEI......................................... ...............
Reedy Creek Improvement District................ RC........................................... ...............
Sacramento Municipal Utility District........... SMUD......................................... ...............
Salt River Project.............................. SRP.......................................... ...............
Santee Cooper................................... SC........................................... ...............
SaskPower Grid Control Centre................... SPC.......................................... X
Seattle City Light.............................. SCL.......................................... ...............
Seminole Electric Cooperative................... SEC.......................................... ...............
Sierra Pacific Power Co.--Transmission.......... SPPC......................................... ...............
South Carolina Electric & Gas Company........... SCEG......................................... ...............
South Mississippi Electric Power Association.... SME.......................................... ...............
South Mississippi Electric Power Association.... SMEE......................................... ...............
Southeastern Power Administration--Hartwell..... SEHA......................................... ...............
Southeastern Power Administration--Russell...... SERU......................................... ...............
Southeastern Power Administration--Thurmond..... SETH......................................... ...............
Southern Company Services, Inc.................. SOCO......................................... ...............
Southern Illinois Power Cooperative............. SIPC......................................... ...............
Southern Indiana Gas & Electric Co.............. SIGE......................................... ...............
Southern Minnesota Municipal Power Agency....... SMP.......................................... ...............
Southwest Power Pool............................ SWPP......................................... ...............
Southwestern Power Administration............... SPA.......................................... ...............
Southwestern Public Service Company............. SPS.......................................... ...............
Sunflower Electric Power Corporation............ SECI......................................... ...............
Tacoma Power.................................... TPWR......................................... ...............
Tampa Electric Company.......................... TEC.......................................... ...............
Tennessee Valley Authority ESO.................. TVA.......................................... ...............
Trading Hub..................................... HUB.......................................... ...............
TRANSLink Management Company.................... TLKN......................................... ...............
Tucson Electric Power Company................... TEPC......................................... ...............
Turlock Irrigation District..................... TIDC......................................... ...............
Upper Peninsula Power Co........................ UPPC......................................... ...............

[[Page 65540]]

Utilities Commission, City of New Smyrna Beach.. NSB.......................................... ...............
Westar Energy--MoPEP Cities..................... MOWR......................................... ...............
Western Area Power Administration--Colorado- WACM......................................... ...............
Missouri.
Western Area Power Administration--Lower WALC......................................... ...............
Colorado.
Western Area Power Administration--Upper Great WAUE......................................... ...............
Plains East.
Western Area Power Administration--Upper Great WAUW......................................... ...............
Plains West.
Western Farmers Electric Cooperative............ WFEC......................................... ...............
Western Resources dba Westar Energy............. WR........................................... ...............
Wisconsin Energy Corporation.................... WEC.......................................... ...............
Wisconsin Public Service Corporation............ WPS.......................................... ...............
Yadkin, Inc..................................... 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.

EQR Data Dictionary
[Appendix C. Hub]
------------------------------------------------------------------------
HUB Definition
------------------------------------------------------------------------
ADHUB........................ The aggregated Locational Marginal Price
(``LMP'') nodes defined by PJM
Interconnection, LLC as the AEP/Dayton
Hub.
AEPGenHub.................... The aggregated Locational Marginal Price
(``LMP'') nodes defined by PJM
Interconnection, LLC as the AEPGenHub.
COB.......................... The set of delivery points along the
California-Oregon commonly identified as
and agreed to by the counterparties to
constitute the COB Hub.
Cinergy (into)............... The set of delivery points commonly
identified as and agreed to by the
counterparties to constitute delivery
into the Cinergy balancing authority.
Cinergy Hub (MISO)........... The aggregated Elemental Pricing nodes
(``Epnodes'') defined by the Midwest
Independent Transmission System
Operator, Inc., as Cinergy Hub (MISO).
Entergy (into)............... The set of delivery points commonly
identified as and agreed to by the
counterparties to constitute delivery
into the Entergy balancing authority.
FE Hub....................... The aggregated Elemental Pricing nodes
(``Epnodes'') defined by the Midwest
Independent Transmission System
Operator, Inc., as FE Hub (MISO).
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.
Illinois Hub (MISO).......... The aggregated Elemental Pricing nodes
(``Epnodes'') defined by the Midwest
Independent Transmission System
Operator, Inc., as Illinois Hub (MISO).
Mead......................... The set of delivery points at or near
Hoover Dam commonly identified as and
agreed to by the counterparties to
constitute the Mead Hub.
Michigan Hub (MISO).......... The aggregated Elemental Pricing nodes
(``Epnodes'') defined by the Midwest
Independent Transmission System
Operator, Inc., as Michigan Hub (MISO).
Mid-Columbia (Mid-C)......... The set of delivery points along the
Columbia River commonly identified as
and agreed to by the counterparties to
constitute the Mid-Columbia Hub.
Minnesota Hub (MISO)......... The aggregated Elemental Pricing nodes
(``Epnodes'') defined by the Midwest
Independent Transmission System
Operator, Inc., as Minnesota Hub (MISO).
NEPOOL (Mass Hub)............ The aggregated Locational Marginal Price
(``LMP'') nodes defined by ISO New
England Inc., as Mass Hub.
NIHUB........................ The aggregated Locational Marginal Price
(``LMP'') nodes defined by PJM
Interconnection, LLC as the Northern
Illinois Hub.
NOB.......................... The set of delivery points along the
Nevada-Oregon border commonly identified
as and agreed to by the counterparties
to constitute the NOB Hub.
NP15......................... 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.
NWMT......................... The set of delivery points commonly
identified as and agreed to by the
counterparties to constitute delivery
into the Northwestern Energy Montana
balancing authority.
PJM East Hub................. The aggregated Locational Marginal Price
nodes (``LMP'') defined by PJM
Interconnection, LLC as the PJM East
Hub.
PJM South Hub................ The aggregated Locational Marginal Price
(``LMP'') nodes defined by PJM
Interconnection, LLC as the PJM South
Hub.
PJM West Hub................. The aggregated Locational Marginal Price
(``LMP'') nodes defined by PJM
Interconnection, LLC as the PJM Western
Hub.
Palo Verde................... 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.
SOCO (into).................. The set of delivery points commonly
identified as and agreed to by the
counterparties to constitute delivery
into the Southern Company balancing
authority.
SP15......................... 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.
TVA (into)................... The set of delivery points commonly
identified as and agreed to by the
counterparties to constitute delivery
into the Tennessee Valley Authority
balancing authority.

[[Page 65541]]

ZP26......................... 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.
------------------------------------------------------------------------

EQR Data Dictionary
Appendix D. Time Zone
------------------------------------------------------------------------
Time zone Definition
------------------------------------------------------------------------
AD.................................... Atlantic Daylight.
AP.................................... Atlantic Prevailing.
AS.................................... Atlantic Standard.
CD.................................... Central Daylight.
CP.................................... Central Prevailing.
CS.................................... Central Standard.
ED.................................... Eastern Daylight.
EP.................................... Eastern Prevailing.
ES.................................... Eastern Standard.
MD.................................... Mountain Daylight.
MP.................................... Mountain Prevailing.
MS.................................... Mountain Standard.
NA.................................... Not Applicable.
PD.................................... Pacific Daylight.
PP.................................... Pacific Prevailing.
PS.................................... Pacific Standard.
UT.................................... Universal Time.
------------------------------------------------------------------------

EQR Data Dictionary
Appendix E. Units
------------------------------------------------------------------------
Units Definition
------------------------------------------------------------------------
KV.................................... Kilovolt.
KVA................................... Kilovolt Amperes.
KVR................................... Kilovar.
KW.................................... Kilowatt.
KWH................................... Kilowatt Hour.
KW-DAY................................ Kilowatt Day.
KW-MO................................. Kilowatt Month.
KW-WK................................. Kilowatt Week.
KW-YR................................. Kilowatt Year.
MVAR-YR............................... Megavar Year.
MW.................................... Megawatt.
MWH................................... Megawatt Hour.
MW-DAY................................ Megawatt Day.
MW-MO................................. Megawatt Month.
MW-WK................................. Megawatt Week.
MW-YR................................. Megawatt Year.
RKVA.................................. Reactive Kilovolt Amperes.
FLAT RATE............................. Flat Rate.
------------------------------------------------------------------------

EQR Data Dictionary
Appendix F. Rate Units
------------------------------------------------------------------------
Rate units Definition
------------------------------------------------------------------------
$/KV.................................. dollars per kilovolt.
$/KVA................................. dollars per kilovolt amperes.
$/KVR................................. dollars per kilovar.
$/KW.................................. dollars per kilowatt.
$/KWH................................. dollars per kilowatt hour.
$/KW-DAY.............................. dollars per kilowatt day.
$/KW-MO............................... dollars per kilowatt month.
$/KW-WK............................... dollars per kilowatt week.
$/KW-YR............................... dollars per kilowatt year.
$/MW.................................. dollars per megawatt.
$/MWH................................. dollars per megawatt hour.
$/MW-DAY.............................. dollars per megawatt day.
$/MW-MO............................... dollars per megawatt month.
$/MW-WK............................... dollars per megawatt week.
$/MW-YR............................... dollars per megawatt year.
$/MVAR-YR............................. dollars per megavar year.
$/RKVA................................ dollars per reactive kilovar
amperes.
CENTS................................. cents.
CENTS/KVR............................. cents per kilovolt amperes.
CENTS/KWH............................. cents per kilowatt hour.
FLAT RATE............................. rate not specified in any other
units.
------------------------------------------------------------------------

[FR Doc. E8-26209 Filed 11-3-08; 8:45 am]

BILLING CODE 6717-01-P