Revisions to Electric Quarterly Report Filing Process, 71288-71312 [2012-28230]
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
outweighed the demand for labor and
the number of requests received for CW
classification in fiscal year 2012 to date
provides a more appropriate baseline for
the maximum number of transitional
workers in the CNMI.
All requests received to date were
submitted during fiscal year 2012, as the
final rule took effect shortly after the
beginning of that fiscal year. USCIS has
not completed adjudication of these
requests but anticipates doing so before
the end of the current calendar year.
These requests, to the extent they are
granted, will be counted under the fiscal
year 2012 cap of 22,416. The vast
majority of CW petitions were filed by
CNMI employers in November 2011,
shortly before the expiration of
‘‘grandfathered’’ CNMI work
authorization on November 27, 2011.
See 48 U.S.C. 1806(e)(2). For these
reasons, DHS believes that the number
of requested CW–1 workers to date in
fiscal year 2012 is an accurate baseline
to use in determining the likely demand
in fiscal year 2013.
The CNRA requires an annual
reduction in the number of transitional
workers (and complete elimination of
the CW nonimmigrant classification by
the end of the transition period) but
does not mandate a specific reduction.
See 48 U.S.C. 1806(d)(2). In addition, 8
CFR 214.2(w)(1)(viii)(C) provides that
the numerical limitation for any fiscal
year will be less than the number for the
previous fiscal year, and it will be
reasonably calculated to reduce the
number of CW–1 nonimmigrant workers
to zero by the end of the transition
period.
To comply with these requirements,
meet the CNMI’s labor market’s needs,
and provide opportunity for growth,
DHS has set the numerical limitation for
fiscal year 2013 at 15,000. DHS
calculated this figure by first taking the
number of CW–1 nonimmigrant workers
needed based on fiscal year 2012 filings
to date of 12,247 (or 11,927, taking into
account 320 denials to date), which
rounded to the nearest thousand is
12,000. DHS then added an additional
25 percent to the 12,000 to
accommodate possible economic growth
that might lead to a need for additional
CW workers, for a total of 15,000.
Accordingly, DHS reduces the number
of transitional workers from the current
fiscal year numerical limitation of
22,416, and establishes the maximum
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number of CW–1 visas available for
fiscal year 2013 at 15,000.
This number of CW–1 workers will be
available beginning on October 1, 2012.
DHS may adjust the numerical
limitation for a fiscal year or other
period, in its discretion, at any time via
notice in the Federal Register. See 8
CFR 214.2(w)(1)(viii)(D). Consistent
with the rules applicable to other
nonimmigrant worker visa
classifications, if the numerical
limitation for the fiscal year is not
reached, the unused numbers do not
carry over to the next fiscal year. See 8
CFR 214.2(w)(1)(viii)(E).
Petitions requesting a validity start
date within fiscal year 2013 will be
counted against the 15,000 limit. As
such, each CW–1 worker who is listed
on a Form I–129CW is counted against
the numerical limitation at the time
USCIS receives the petition. Counting
the petitions in this manner will help
ensure that USCIS does not approve
requests for more than 15,000 CW–1
workers. If the number of CW–1 workers
approaches the 15,000 limit, USCIS will
hold any subsequently-filed petition
until a final determination is made on
the petitions that are already included
in the numerical count. Subsequentlyfiled petitions will be forwarded for
adjudication in the order in which they
were received until USCIS has approved
petitions for the maximum number of
CW workers; any remaining petitions
that were held or that are newly
received will be rejected.
This document does not affect the
status of aliens who hold CW–1
nonimmigrant status. Aliens currently
holding such status, however, will be
affected by this document when they
apply for an extension of their CW–1
classification, or a change of status from
another nonimmigrant status to CW–1
status.
This document does not affect the
status of any alien currently holding
CW–2 status as the spouse or minor
child of a CW–1 nonimmigrant. This
document also does not directly affect
the ability of any alien to extend or
otherwise obtain CW–2 status, as the
numerical limitation applies to CW–1
principals only. Aliens seeking CW–2
status may be affected indirectly by the
applicability of the cap to the CW–1
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principals from whom their status is
derived.
Janet Napolitano,
Secretary.
[FR Doc. 2012–29025 Filed 11–29–12; 8:45 am]
BILLING CODE 9111–97–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
18 CFR Part 35
[Docket No. RM12–3–000; Order No. 770]
Revisions to Electric Quarterly Report
Filing Process
Federal Energy Regulatory
Commission, DOE.
ACTION: Final rule.
AGENCY:
The Federal Energy
Regulatory Commission (Commission)
amends its regulations to change the
process for filing Electric Quarterly
Reports (EQR). Due to technology
changes that will render the current
filing process outmoded, ineffective,
and unsustainable, the Commission will
discontinue the use of Commissiondistributed software to file an EQR.
Instead, the Commission adopts a webbased approach to filing EQRs that will
allow a public or non-public utility to
file an EQR directly through the
Commission’s Web site, either through a
web interface or by submitting an
Extensible Mark-Up Language-formatted
file. By adopting a process with two
options for filing EQRs, the Commission
seeks to provide the flexibility needed
to accommodate a public or non-public
utility’s technical preference. The
Commission also requires a public or
non-public utility to identify itself with
a company identification number rather
than the existing software-based EQR
identifier. The changes to the process
for filing EQRs will apply to EQR filings
beginning with the third quarter 2013
EQR, which will provide data for July
through September 2013.
DATES: Effective date: This rule will
become effective April 1, 2013.
FOR FURTHER INFORMATION CONTACT:
Connie Caldwell, Office of Enforcement,
Federal Energy Regulatory
Commission, 888 First Street NE.,
Washington, DC 20426, (202) 502–
6489, Connie.Caldwell@ferc.gov.
SUMMARY:
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Christina Switzer, Office of General
Counsel, Federal Energy Regulatory
Commission, 888 First Street NE.,
Washington, DC 20426, (202) 502–
6379, Christina.Switzer@ferc.gov.
71289
Final Rule
SUPPLEMENTARY INFORMATION:
Before Commissioners: Jon Wellinghoff,
Chairman; Philip D. Moeller, John R.
Norris, Cheryl A. LaFleur, and Tony T.
Clark.
(Issued November 15, 2012)
Table of Contents
Paragraph
Nos.
I. Introduction ...........................................................................................................................................................................................
II. Background ...........................................................................................................................................................................................
III. Discussion ...........................................................................................................................................................................................
A. Need for Changing the Current EQR Filing Process ..................................................................................................................
1. NOPR Proposal .......................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
B. Option One—Web Interface .........................................................................................................................................................
1. NOPR Proposal .......................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
C. Option 2—XML-Formatted File ...................................................................................................................................................
1. NOPR Proposal .......................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
D. Validation ......................................................................................................................................................................................
1. NOPR ......................................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
E. Company Registration System .....................................................................................................................................................
1. NOPR Proposal .......................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
F. Implementation and Compliance .................................................................................................................................................
1. NOPR Proposal .......................................................................................................................................................................
2. Comments ...............................................................................................................................................................................
3. Commission Determination ...................................................................................................................................................
IV. Information Collection Statement ......................................................................................................................................................
V. Environmental Analysis ......................................................................................................................................................................
VI. Regulatory Flexibility Act ..................................................................................................................................................................
VII. Document Availability ......................................................................................................................................................................
VIII. Effective Date and Congressional Notification ...............................................................................................................................
Appendix A: List of Commenters
Appendix B: EQR Data Dictionary
I. Introduction
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1. The Federal Energy Regulatory
Commission (Commission) adopts
changes to the method for filing Electric
Quarterly Reports (EQR). Due to
technology changes that will render the
current filing process outmoded,
ineffective, and unsustainable, the
Commission will discontinue the use of
Commission-distributed software (EQR
software) to file an EQR. Instead, the
Commission adopts a web-based
approach that will allow a public or
non-public utility to file an EQR directly
through the Commission’s Web site,
either through a web interface or by
submitting an Extensible Mark-Up
Language (XML)-formatted 1 file (XML
option). The Commission also requires a
public utility or non-public utility to
1 XML schemas facilitate the sharing of data
across different information systems, particularly
via the Internet, by structuring the data using tags
to identify particular data elements. For example,
each filed EQR will include tags for the relevant
information. The tagged information can be
extracted and separately searched.
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identify itself with a company
identification number (Company
Identifier) rather than the existing
software-based EQR identifier (Personal
Identification Number (PIN)). The
changes to the process for filing EQRs
will apply to EQR filings beginning with
the third quarter (Q3) 2013 EQR, which
will provide data for July through
September 2013.
2. Before turning to the requirements
in this Final Rule, it is important to
explain certain terms. In the Notice of
Proposed Rulemaking (NOPR), the
Commission often used the term ‘‘filer’’
in the description of the two new filing
options.2 We find that using the term
‘‘filer’’ created confusion because it was
not clear whether the Commission was
talking about a public or non-public
utility, its agent, or a respondent. Thus,
in this Final Rule, we use the phrase
‘‘EQR seller’’ to mean companies that
are authorized to sell power under Part
2 Revisions to Electric Quarterly Report Filing
Process, Notice of Proposed Rulemaking, FERC
Stats. & Regs. ¶ 32,689 (2012) (NOPR).
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19
19
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24
30
30
31
33
37
37
38
47
53
64
65
71
74
35 of the Commission’s regulations 3 as
well as non-public utilities 4 that are
3 See Revised Public Utility Filing Requirements,
Order No. 2001, 67 FR 31044 (May 8, 2002), FERC
Stats. & Regs. ¶ 31,127 at 30,116, reh’g denied,
Order No. 2001–A, 100 FERC ¶ 61,074, reh’g
denied, Order No. 2001–B, 100 FERC ¶ 61,342,
order directing filing, Order No. 2001–C, 101 FERC
¶ 61,314 (2002), order directing filing, Order No.
2001–D, 102 FERC ¶ 61,334, order refining filing
requirements, Order No. 2001–E, 105 FERC ¶ 61,352
(2003), order on clarification, Order No. 2001–F,
106 FERC ¶ 61,060 (2004), order revising filing
requirements, Order No. 2001–G, 72 FR 56735 (Oct.
4, 2007), 120 FERC ¶ 61,270, at PP 10–11, order on
reh’g and clarification, Order No. 2001–H, 73 FR
1876 (Jan. 10, 2008), 121 FERC ¶ 61,289 (2007),
order revising filing requirements, Order No. 2001–
I, 73 FR 65526 (Nov. 4, 2008), FERC Stats. & Regs.
¶ 32,282 (2008).
4 ‘‘Non-public utility’’ refers to a market
participant that is not a public utility under section
201(f) of the FPA. FPA section 201(f) provides: No
provision in this Part shall apply to, or be deemed
to include, the United States, a State or any political
subdivision of a State, an electric cooperative that
receives financing under the Rural Electrification
Act of 1936 (7 U.S.C. 901 et seq.) or that sells less
than 4,000,000 megawatt hours of electricity per
year, or any agency, authority, or instrumentality of
any one or more of the foregoing, or any corporation
which is wholly owned, directly or indirectly, by
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required to comply with the EQR filing
requirements pursuant to the Electricity
Market Transparency Provisions of
Section 220 of the Federal Power Act,
Order No. 768.5 We use the phrase
‘‘EQR agent’’ to mean an entity that an
EQR seller designates to file on its
behalf. An EQR seller will be able to
designate multiple EQR agents.6 Even
when an EQR agent files on an EQR
seller’s behalf, the legal obligation for
complying with the EQR requirements
remains with the companies that are
authorized to sell power under Part 35
of the Commission’s regulations and
non-public utilities, and any
inaccuracies are their responsibility.
II. Background
3. The purpose of the EQR is to
make available for public inspection, in a
convenient form and place all relevant
information relating to public utility rates,
terms, and conditions of service; ensure that
information is available in a standardized,
user friendly format; and meet the
Commission’s electronic filing option
obligation. [Footnote omitted.] These actions
also will allow the public to better participate
in and obtain the full benefits of wholesale
electric power markets while minimizing the
reporting burden on public utilities.7
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The EQR allows public utilities to
fulfill their responsibility under section
205(c) 8 of the FPA to have rates on file
in a convenient form and place.9 Nonpublic utilities will file EQRs to meet
the requirements under section 220 of
the FPA,10 as explained in the
Electricity Market Transparency
Provisions of Section 220 of the Federal
Power Act, Order No. 768.11
4. Prior to the issuance of Order No.
2001, the Commission required all
public utilities to file in paper format all
short-term and long-term service
any one or more of the foregoing, or any officer,
agent, employee of any of the foregoing acting as
such in the course of his official duty, unless such
provision makes specific reference thereto. 16
U.S.C. 824(f).
5 77 FR 61896 (Oct. 11, 2012), FERC Stats. & Regs.
¶ 31,336 (2012)(Transparency Rule). In that
rulemaking, the Commission extended the EQR
filing requirements to non-public utilities above a
de minimis market presence threshold and adopted
new filing requirements for both public and nonpublic utilities.
6 The process for designating an EQR agent is
discussed in detail below. See supra, section III.E.
7 Order No. 2001, FERC Stats. & Regs. ¶ 31,127 at
30,116.
8 16 U.S.C. 824d(c).
9 Order No. 2001, FERC Stats. & Regs. ¶ 31,127 at
P 31.
10 EPAct 2005, Public Law 109–58, 119 Stat. 594
(2005).
11 Transparency Rule, FERC Stats. & Regs.
¶ 31,336. In that rulemaking, the Commission
extended the EQR filing requirements to non-public
utilities above a de minimis market presence
threshold and adopted new filing requirements for
both public and non-public utilities.
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agreements for cost-based and marketbased power sales as well as service
agreements for generally applicable
services (such as point-to-point
transmission service). In Order No.
2001, the Commission replaced the
paper filing requirement with an
electronic filing requirement.12
The Commission specified that EQRs
should ‘‘be prepared in conformance
with the Commission’s software and
guidance posted and available for
downloading from the FERC Web site
(https://www.ferc.gov).’’ 13 Since the
fourth quarter of 2002, the Commission
has posted on its Web site a
Commission-developed Visual FoxPro
application for filing EQRs (EQR
software) that runs on Microsoft
Windows-based computers.14
5. On June 21, 2012, the Commission
issued a NOPR in this proceeding to
propose changes to the EQR electronic
filing process.15 On July 11, 2012, the
Commission held a technical conference
to present the two new proposed
options for filing EQRs. On July 27,
2012, the Commission posted on its
Web site a draft of the XML schema
(draft XML schema) for the proposed
XML option so that interested parties
would be able to view the draft XML
schema prior to submitting comments
on the NOPR.16 The Commission also
posted a ‘‘Frequently Asked Questions’’
document on its Web site in response to
questions raised at the July 11 technical
conference.17 The Commission received
12 The Commission has refined and clarified the
EQR filing requirements set forth in Order No. 2001
in response to changes in the industry and the
Commission’s rules and regulations. For example,
the Commission has required EQR sellers to report
all transmission capacity reassignments and
proposed to revise the EQR Data Dictionary to add
‘‘Simultaneous Exchange’’ to the list of available
product names. See Preventing Undue
Discrimination and Preference in Transmission
Service, Order No. 890, 72 FR 12266 (Mar. 15,
2007), FERC Stats. & Regs. ¶ 31,241, at P 817, order
on reh’g, Order No. 890–A, 73 FR 2984 (Jan. 16,
2008), FERC Stats. & Regs. ¶ 31,261 (2007), order on
reh’g and clarification, Order No. 890–B, 73 FR
39092 (July 8, 2008), 123 FERC ¶ 61,299 (2008),
order on reh’g, Order No. 890–C, 74 FR 12540 (Mar.
25, 2009),126 FERC ¶ 61,228 (2009), order on
clarification, Order No. 890–D, 74 FR 61511 (Nov.
25, 2009), 129 FERC ¶ 61,126 (2009); Revised Public
Utility Filing Requirements for Electric Quarterly
Reports, Notice of Proposed Rulemaking, 77 FR
16494 (Mar. 21, 2012), FERC Stats. & Regs. ¶ 32,687
(2012).
13 18 CFR 35.10b.
14 See Notice Providing Detail On Electric
Quarterly Reports Software Availability and
Announcing Schedule for Software Demonstrations,
Docket No. RM01–8–000 (Dec. 20, 2002).
15 NOPR, FERC Stats. & Regs. ¶ 32,689.
16 Notice of Availability of Draft XML Schema,
Docket No. RM12–3–000 (July 27, 2012). The draft
XML-schema is available on the Commission’s Web
site at https://www.ferc.gov/docs-filing/eqr.asp.
17 The Frequently Asked Questions document is
also available on the Commission’s Web site at
https://www.ferc.gov/docs-filing/eqr.asp.
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eight comments in response to the
NOPR.18
III. Discussion
A. Need for Changing the Current EQR
Filing Process
1. NOPR Proposal
6. In the NOPR, the Commission
stated that, pursuant to the
Commission’s regulations,19 EQR sellers
and agents must download EQR
software from the Commission’s Web
site. The Commission explained that
this software was built with Visual
FoxPro development tools and must be
installed on a Windows-based
computer. The Commission identified
certain disadvantages with the current
filing process, such as the fact that
Microsoft, the vendor of Visual FoxPro,
announced in 2007 that it would no
longer sell or issue new versions of
Visual FoxPro and would not provide
support for the software after 2015. The
Commission also explained that data
limitations make the EQR software
outmoded, ineffective, and
unsustainable.20 The Commission stated
that the changes proposed in the NOPR
support the goals of Executive Order
13579 21 because the Commission
proposed to modify a filing process that
has become outmoded and
ineffective. 22
2. Comments
7. Commenters understand the
technical limitations of the existing
software and the Commission’s decision
to discontinue it.23 Pacific Gas and
Electric commends the Commission for
its ongoing efforts to enhance the
efficiency of the EQR data gathering and
reporting process.24
3. Commission Determination
8. We conclude that the proposed
changes to the method for filing EQRs
are appropriate. As explained in the
NOPR, continuing to rely on the current
EQR software is unsustainable because
Microsoft will no longer sell or issue
18 See Appendix A for a list of commenters and
their abbreviated names used here. We note that
Southern California Edison joins EEI’s comments.
19 18 CFR 35.10b.
20 NOPR, FERC Stats. & Regs. ¶ 32,689 at P 4.
21 Regulation and Independent Regulatory
Agencies, Exec. Order 13579, 76 FR 41587 (2011).
Through this Executive Order, the President
requested that executive agencies retrospectively
analyze their agency’s rules and that those found to
be outmoded, ineffective, insufficient, or
excessively burdensome be modified, streamlined,
expanded, or repealed in accordance with the
results of that analysis.
22 NOPR, FERC Stats. & Regs. ¶ 32,689 at P 5.
23 See, e.g., Idaho Power at 2; Pacific Gas and
Electric at 1.
24 Pacific Gas and Electric at 1.
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new versions of Visual FoxPro.25
Further, the data limitations of the
current software make it untenable for
use going forward.26 As the Commission
also explained, the move from a
software-based approach to a web-based
approach will eliminate the need for
EQR sellers and agents to download
software from the Commission’s Web
site.27 In addition, a web-based
approach for EQR filing is deviceindependent, which eliminates the need
for EQR sellers and agents to use a
Windows-based computer to file an
EQR.28 We also note that the new filing
process will allow EQR sellers and
agents to access and revise EQR data
filed prior to Q3 2013.
B. Option One—Web Interface
1. NOPR Proposal
9. In the NOPR, the Commission
proposed to offer a web interface on the
Commission’s Web site that allows EQR
sellers and agents to continue to enter
data in the comma-delimited text (CSV)
format but without the need to
download the EQR software.29 The
Commission stated that this option
would minimize the changes for EQR
sellers and agents and streamline the
filing process by eliminating the need
for EQR sellers and agents to enter or
import the data into a software
application.
2. Comments
10. Commenters generally support the
web interface option as long as the
transition from the current filing process
is not overly difficult or costly.30 Some
commenters argue that they cannot fully
comment on the web interface option
without a live demonstration.31 EEI
believes that the web interface will
allow (1) companies to upload complete
sets of data from prior EQRs, and then
edit the information to reflect changes
in the current quarter, rather than
having to start each new EQR from a
blank slate; (2) companies to upload
new data in the same CSV format as the
current software; and (3) multiple staff
within each company or outside the
company with the company’s
permission to fill out and review
portions of an EQR, though only one
person can be editing a particular EQR
at any one time.32
25 NOPR,
FERC Stats. & Regs. ¶ 32,689 at P 4.
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26 Id.
27 Id.
P 6.
28 Id.
29 Id.
30 See,
e.g., EEI at 4; Energy Services Providers at
3; Idaho Power at 3.
31 See, e.g., Idaho Power at 3; Pacific Gas and
Electric at 4–5.
32 EEI at 5.
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11. EPSA requests that the
Commission clarify that the proposed
web interface option will be a long-term
alternative to the XML option that will
not be phased out in favor of the latter.33
3. Commission Determination
12. We adopt the web interface as one
of two new EQR filing options. As
explained in the NOPR, this option will
minimize the changes for EQR sellers
and agents and streamline the filing
process by eliminating the need for EQR
sellers and agents to first enter or import
the data into a software application then
send it, via Internet, to the Commission.
We are offering this option to make the
transition from the current EQR
software to the web interface minimally
disruptive. We direct Commission staff
to continue to be available to answer
questions, conduct technical
conferences, and post guidance
documents on the Commission’s Web
site as needed.
13. We emphasize that, as explained
in the NOPR, the web interface will
allow EQR sellers and agents to
continue to enter data in much the same
way as they currently do: By entering
individual fields by hand (an option
used primarily by EQR sellers that have
little data to report) or by uploading
data in CSV format. Also, we note that,
except for minor changes, the data
elements of the EQR will remain the
same.34
14. We also point out that, in
designing the web interface,
Commission staff has sought to provide
the same, if not better, functionality
than is provided in the current EQR
software. For example, once one quarter
has been filed in the web interface, a
copy forward function will allow EQR
sellers and agents to copy forward
complete sets of identification and
contract data and then edit the data to
reflect changes in the current quarter.35
Also, an EQR seller will be able to
designate more than one EQR agent to
input data on its behalf. Finally, the use
33 EPSA
at 3.
only proposed changes to the EQR data
elements adopted here relate to the addition of a
field for the identification of the EQR seller and the
elimination of the respondent field. See discussion
infra section III.E. For recent changes to the EQR
filing requirements, see Transparency Rule, FERC
Stats. & Regs. ¶ 31,336.
35 To assist in the transition to the web interface
option, the EQR seller or agent can import contract
data from the Q2 2013 EQR filing made via the
current EQR software into the new web interface
after the file is revised to accommodate any new
required fields. See discussion infra section III.F.
However, as under the current EQR software, the
web interface will not permit the EQR seller or
agent to copy transaction data forward because the
transactions must correspond to the EQR’s
designated calendar quarter.
34 The
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of a web interface will minimize, if not
eliminate, many common EQR filing
problems that are due to (1) conflicts
between the current EQR software and
other software on the EQR seller or
agent’s computer or (2) issues associated
with initiating and supporting the
communication functions of the current
EQR software.
15. Finally, we intend to support the
web interface option until such time as
it is no longer needed.
C. Option 2—XML-Formatted File
1. NOPR Proposal
16. In the NOPR, the Commission
proposed a second EQR filing option
that allows EQR sellers and agents to
file EQR data via XML-formatted files.36
The Commission identified various
advantages to the XML option. For
example, an XML schema allows EQR
sellers and agents to test whether their
data is consistent with the filing
standards before uploading it to the
Commission, thereby improving their
ability to comply with the EQR filing
requirement and increasing confidence
that the Commission receives the
intended information.37
2. Comments
17. Pacific Gas and Electric believes
that the XML option is a promising
solution.38 Pacific Gas and Electric
states that the XML format provides the
greatest flexibility for processing large
amounts of data and the greatest
opportunity to accurately validate data.
However, Pacific Gas and Electric notes
that converting data to XML format
requires a software program, authored
in-house or by a vendor, that can create,
submit, and store and manage the EQR
report.39 Idaho Power supports this
filing option if it is similar to the current
filing method and is not overly
burdensome and/or does not require
major changes to Idaho Power’s internal
systems.40 Other commenters do not
object to the XML option if it is
voluntary and not the sole means of
submission.41 EEI supports allowing
companies to switch between the web
interface and XML options from one
EQR to another.42
3. Commission Determination
18. We adopt the XML option as the
second of two new filing options. This
36 NOPR,
FERC Stats. & Regs. ¶ 32,689 at P 7.
37 Id.
38 Pacific
Gas and Electric at 6.
at 5.
40 Idaho Power at 2.
41 See, e.g., EEI at 7; Energy Services Providers at
3; EPSA at 4; Idaho Power at 4–5.
42 EEI at 7.
39 Id.
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option allows EQR sellers and agents to
file their EQR data in an XML-formatted
file. While we find that allowing EQR
sellers and agents to use the XML option
offers several advantages, as highlighted
by Pacific Gas and Electric, and will
facilitate the filing of EQRs, we stress
that using the XML option is voluntary.
Alternatively, EQR sellers and agents
can choose to file via the web interface.
An EQR seller may use the web
interface to file their EQR for one
quarter and use the XML option to file
their EQR in another quarter, but an
EQR seller cannot use both options to
file its EQR in the same quarter.
D. Validation
1. NOPR
19. In the NOPR, the Commission
explained that an XML schema includes
rules and data checks. This allows EQR
sellers and agents to test the consistency
of their data with the Commission’s
filing standards, thereby improving the
ability to comply with EQR filing
requirements and ensures that the
Commission receives the intended
information.43 The Commission further
noted in the NOPR that these data
checks are not available in a CSV file.
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2. Comments
20. Energy Compliance Consulting
requests that the Commission make
available as soon as possible all of the
criteria that the Commission will use to
validate an EQR prior to its acceptance
for filing.44 Energy Compliance
Consulting notes that, contrary to the
statement in the posted FAQ document,
the draft XML schema posted on the
Commission’s Web site contains data
elements that EQR filers are not
currently required to provide.45 Energy
Compliance Consulting requests that the
Commission explain this discrepancy.46
21. EPSA argues that any new filing
method should meet or exceed the
validation capabilities of the Visual
FoxPro-based EQR software.47 EPSA
asserts that EQR users have not been
presented with meaningful information
on how validation checks will be
designed for either the web interface or
the XML filing option.48 EEI believes
that the web interface will allow
companies to upload, edit, and check
for errors in the data before actually
filing the EQR; provide pre-filing error
checks and validations for completeness
and compliance with filing
requirements; and provide error
messages to allow companies to correct
problems before filing their EQRs.49 EEI
and Links Technology Solutions ask
that the Commission provide a
permanent testing facility (sandbox),
like the eTariff sandbox test site, so that
filers can check the basic construction
of their XML files and perform basic
types of data checks.50
22. Based on information provided
during the technical conference, Pacific
Gas and Electric argues that providing
email notification for any validation
errors encountered during upload may
cause a significant delay in correcting
errors and providing timely EQRs.51
Pacific Gas and Electric claims that
using email messages reduces EQR
filers’ ability to be quickly alerted of
validation errors, which undercuts the
Commission’s effort to create a new
system on par with, or better than, the
Visual FoxPro-based EQR software.52
Pacific Gas and Electric suggests the
web-based system should (1) include
on-screen error reports that are
interactive (with links to the error
records) or a user-friendly form (like a
spreadsheet) that allows the EQR filer to
immediately and accurately address
validation errors, and (2) allow batch
corrections to the error records.53 Pacific
Gas & Electric notes that generally
accepted data validation rules, which
require the validation process to stop
when a critical error is detected, leave
open the possibility that after receiving
an error notification and remedying a
set of errors, an EQR filer could receive
further error messages every time the
validation routine stops because a
critical error is detected.54 Pacific Gas
and Electric is concerned about the
impact of this process on timely EQR
filing.55
23. Pacific Gas and Electric also states
that, while it generally supports the
Commission’s proposal to alter the EQR
user authentication methodology, it is
concerned about who will have access
to the sandbox.56 Pacific Gas and
Electric asserts that restricting access to
only those people authorized to file on
behalf of a client, as suggested at the
technical conference, will reduce the
filing entities’ current ability to allow
anyone within a given company to
download a copy of the current EQR
distributed software, load data, and run
49 EEI
at 5.
e.g., EEI at 8; Links Technology Solutions
50 See,
at 2.
43 NOPR,
FERC Stats. & Regs. ¶ 32,689 at P 7.
44 Energy Compliance Consulting at 3.
45 Id. at 2–3.
46 Id. at 3.
47 EPSA at 4–5.
48 EPSA at 5.
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51 Pacific
Gas and Electric at 7.
52 Id.
53 Id.
validation checks to test some or all of
its filing data.57 Thus, Pacific Gas and
Electric requests that the Commission
provide authentication protocols in the
new system that address these
concerns.58
3. Commission Determination
24. We find that the validation
process in the web interface and XMLformat options will be similar to or
better than the validation process in the
current EQR software. We further find
that the validation processes strike an
appropriate balance between the needs
identified by commenters and the
Commission’s resources. We appreciate
Energy Compliance Consulting’s request
that all the criteria which will be used
to validate an EQR filing prior to its
acceptance be made available as soon as
possible. The validation criteria are
currently under development, and the
Commission will make these available
to the public as soon as they are
complete. As for the discrepancy
between the posted draft XML schema
and FAQ document, we note that the
draft XML schema mistakenly included
additional data elements that were not
included in the NOPR.
25. Under both of the new EQR filing
options, EQR sellers and agents will be
able to log into their eRegistration
accounts, load data and run the
validation check. Once an EQR is
submitted, the EQR seller or agent that
submitted the EQR will receive the
following three emails: (1) A receipt
email that acknowledges that the EQR
has been received; (2) a validation email
that will list any business rule errors,
such as listing a transaction under a
contract without entering the contract in
the contract section; and (3) an
acceptance/rejection email stating that
the EQR is accepted if all validations are
passed or is rejected if any validations
fail. The EQR seller and all of its
designated EQR agents will receive the
validation email and the acceptance/
rejection email. The validation email
will provide a list of the errors that are
contained in submitted data. The system
will review the entire submission prior
to creating and sending the validation
report. Due to the number of potential
occurrences, the report may not list all
instances of the error, but the EQR seller
or agent will be alerted that that type of
error has occurred. Once the EQR seller
or agent has found and corrected all
errors in the submission, the EQR data
will be accepted for filing.
26. In addition, both filing options
will include a ‘‘Test Only’’ option so
54 Id.
55 Id.
56 Id.
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57 Id.
at 7–8.
at 8.
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58 Id.
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that EQR sellers and agents can submit
their filing for data validation prior to
final submission. With respect to the
web interface option, we also have taken
steps to address EPSA’s request for intime validation checks by including
some validation checks that will appear
on-screen as the EQR seller or agent
inputs the data. These validation checks
are the same as or similar to the
validation checks that appear when an
EQR seller or agent uses the current
EQR software. For example, an onscreen error message will appear if a
field is left empty that must be filled, or
if an alphabetical character is entered in
a numeric field. After the EQR seller or
agent submits its filing, it will receive a
validation email that will provide
business logic and data format errors
and line numbers within the body of the
email.
27. Pacific Gas and Electric expressed
concern that the issuance of validation
emails after the occurrence of each
critical error may slow the filing
process. We are not able to avoid the
additional time that the detection of
multiple critical errors will add to the
filing process. Validating for business
logic errors after a filing is submitted
will allow the Commission to maintain
the system during high volumes of
filings. However, we note that EQR
sellers and agents will have the option
to run a data validation check prior to
submitting the EQR to the Commission
using the ‘‘Test Only’’ feature, which
should help alleviate Pacific Gas and
Electric’s concerns. Moreover, the
Commission expects that the new EQR
filing process will be able to process
revised EQR data more quickly and
efficiently because it will have the
ability to process only revised data,
rather than needing to process the entire
data set to overwrite the previously
submitted data, as currently is the case.
By decreasing the amount of processing
capability needed for data updates, the
Commission will increase the available
computer capacity for processing the
simultaneous filing of EQRs, resulting in
quicker processing of both EQRs and
revised EQRs. We also encourage EQR
sellers and agents to submit EQRs early
in the filing period, which starts on the
first day after the end of the quarter
providing an entire month to validate
the data.
28. With respect to the XML option,
we do not find an eTariff type sandbox
is necessary because the ability to test
an EQR filing is integrated into the new
system. Specifically, XML files can be
imported into the Web interface, where
the EQR seller or agent can select the
‘‘Test Only’’ option to receive the
validation email for that EQR filing.
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Additionally, EQR sellers and agents
may use one of many XML parser
programs available free on-line to check
whether their XML file is consistent
with the EQR XML schema. The parser
will check for data formatting errors,
which an EQR seller or agent can then
correct. If there are business logic errors
that were undetected by the parser, a
validation email will notify the EQR
seller and agent contacts.
29. We decline to adopt Pacific Gas
and Electric’s request to include the
ability to perform batch corrections to
records that contain errors. The current
EQR software does not provide a way to
perform batch corrections; and we are
not persuaded to include that capability
in the new filing options. This
correction method could arbitrarily and
incorrectly change the contents of an
EQR. We note, however, that EQR
sellers and agents who intend to file by
uploading CSV or XML files can
develop their own batch correction
processes to respond to validation
errors.
E. Company Registration System
1. NOPR Proposal
30. In the NOPR, the Commission
proposed to replace the PIN number
identification system with the Company
Registration System used for eTariff
filings.59 The Commission explained
that the PIN system is part of the EQR
software, and as part of the transition
away from this software application, the
Commission must provide a new
manner to identify EQR sellers. The
Commission stated that, as part of the
development of the eTariff system, the
Commission directed each publicly
regulated company to file its tariffs, rate
schedules, jurisdictional contracts, and
other jurisdictional agreements with a
Company Identifier. Accordingly, the
Commission stated that it does not
anticipate that the use of a Company
Identifier in the EQR filing process will
create an undue burden for publicly
regulated companies that file their
Commission-jurisdictional tariffs and
agreements because they already have
Company Identifiers. The Commission
also stated that it did not anticipate that
the use of the Company Identifier will
be unduly burdensome for an EQR filer
that does not have an existing Company
Identifier because the registration
process on the Commission’s Web site is
straightforward and no more difficult
than the current filer identification
process. The Commission also noted
that an advantage of using the Company
Identifier for EQR filings is that it will
59 NOPR,
PO 00000
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71293
make filer identification consistent with
other filings.60
2. Comments
31. EEI supports the Commission’s
plan to continue to accommodate a wide
variety of EQR filing arrangements,
including (1) filings submitted on behalf
of respondents that are not registered
companies (i.e., entities that do not have
Company Identifiers); (2) a single
respondent filing on behalf of multiple
sellers; (3) a single seller submitting
multiple EQRs for the same quarter
through different respondents; (4) a
seller that consists of multiple registered
companies or an unregistered service
company; and (5) law-firm personnel
and others filing as agents for
respondents.61 However, EEI states that
the Commission may need to provide
additional flexibility as to individuals
and entities that can register and obtain
a Company Identifier using the
eRegistration system.62 EEI asks the
Commission to allow filings by anyone
who has the necessary Company
Identifier and password without
limiting filings to a pre-approved list of
specific individuals.63 EEI urges the
Commission to post instructions for
company registration similar to the
instructions that the Commission posted
for company registration for eTariff.64
32. Based on information provided at
the technical conference, EPSA asks the
Commission to reconsider requiring
companies to designate in advance of
making a filing who is authorized to
make EQR filings.65 EPSA states that its
members have cautioned that requiring
companies to designate in advance who
is permitted to file their EQRs may
prove more unwieldy than
anticipated.66 EPSA states that its
members own numerous project
companies and that the administrative
burden associated with initially
designating agents and back-up agents
on what could be over fifty company
registrations and changing each of those
delegations in anticipation of staffing
changes or in case of emergencies is
unnecessary.67 EPSA further states that
60 Id.
61 EEI
at 3.
at 4. This document is located on the
Commission’s Web site at https://www.ferc.gov/docsfiling/company-registration-instruct.pdf, and the
current version is dated October 6, 2011.
63 Id.
64 Id. (citing FERC Secretary of the Commission,
eTariff Instructions for Company Registration
(2009), https://www.ferc.gov/docs-filing/companyregistration-instruct.pdf (The Commission up-dated
the instructions on October 6, 2011)).
65 EPSA at 5.
66 Id.
67 Id.
62 Id.
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there are already security protections in
place to ensure an authorized person is
making filings with the Commission.68
Finally, EPSA asserts that, because
Commission staff’s approval of
modifications to a company’s
registration can take up to 24 hours to
become effective, a company’s filing
may become untimely.69 EPSA states
that, in the eTariff context, where
delegations are not needed and thus
modifications to company registration
are not routine, the modification of
company registrations has delayed
filings.70
3. Commission Determination
33. The Commission adopts the
requirement for EQR sellers to identify
themselves using a Company Identifier.
As explained in the NOPR, the PIN
system is part of the current EQR
software. Therefore, as part of the
transition away from the EQR software,
the Commission must provide a new
manner to identify EQR sellers. Instead
of building a new identification system
for submitting EQRs, we will utilize the
company registration system that was
created for eTariff. Using the company
registration system to identify EQR
sellers allows the Commission to make
filer identification consistent with other
Commission filings and is familiar to
public utilities that use eTariff. Under
the new EQR filing system, all EQR
sellers will be identified in EQR filings
by their Company Identifier.71
34. To make an EQR filing, the EQR
seller will request a Company Identifier
through the Commission’s Company
Registration System.72 The EQR seller
will be able to maintain a list of
eRegistered EQR agents whom the EQR
seller has authorized to submit EQR
filings on its behalf.73 An EQR seller can
designate multiple individuals as its
agents. The EQR agent will use its
eRegistration account to log onto FERC
68 Id.
at 6.
69 Id.
F. Implementation and Compliance
70 Id.
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71 The
current PIN system requires an EQR seller
to share its PIN and password with all individuals
that it wants to allow to file on its behalf, and we
do not consider this to be a safe practice. We
believe that this creates the potential for
unanticipated problems and that it is not the most
secure method of filing.
72 See https://www.ferc.gov/docs-filing/companyreg.asp. Many EQR sellers have a Company
Identifier and do not need to request a new
Company Identifier. If an EQR seller is not sure
whether it already has a Company Identifier, it can
check the list of Company Identifiers on the
Commission’s Web site at https://www.ferc.gov/
industries/electric/gen-info/reg-ent.asp.
73 An individual must eRegister before an EQR
seller can designate that person as an EQR agent.
See https://www.ferc.gov/docs-filing/
eregistration.asp.
VerDate Mar<15>2010
Online,74 and select from a list of EQR
seller(s) that have designated the
individual as EQR agent.
35. We understand that requiring EQR
sellers to designate agents that have
eRegistered is more burdensome than
the current system. However, after the
initial burden of designating EQR
agents, we anticipate that it will be
minimally burdensome for an EQR
seller to manage its EQR agent list. For
instance, since an EQR seller may
designate an unlimited number of
agents, if one agent is unable to file in
a given quarter, another agent will be
able to make the filing. Finally, in
response to EPSA’s concern,
Commission staff will not review
changes that a company makes to the
list of EQR agents associated with its
Company Identifier account. These
changes will be instantaneous.75
36. We note that the new
identification system will provide an
electronic record of the EQR agent(s)
that have filed an EQR on behalf of an
EQR seller. Accordingly, we will
eliminate the respondent fields from the
EQR data dictionary because it no
longer provides useful information to
the Commission or the public. We are
aware that some companies use the
respondent field to indicate that a
service company or parent company is
filing on behalf of several operating
companies or affiliates that are the EQR
sellers. While a parent company or
service company may file EQRs on
behalf of EQR sellers, an individual will
need to be eRegistered and designated
as an agent of the EQR sellers. The
designated agent may then file an EQR
on behalf of the EQR seller. EEI also
suggests that an EQR seller could be a
service company. We note that a service
company may be listed as an EQR seller
if the service company is authorized to
sell power under Part 35 of the
Commission’s regulations, or if a public
utility’s tariff authorizes the service
company to act on its behalf.76
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Jkt 229001
1. NOPR Proposal
37. In the NOPR, the Commission
proposed that implementation of any
changes to the process for filing EQRs
will apply to EQR filings beginning with
the Q3 2013 EQR, providing data for
July through September 2013.77 The
Commission stated that implementing
the changes within that time period
should provide EQR sellers with
sufficient time to weigh the two options
and file their Q3 2013 EQR in a timely
manner.
2. Comments
38. Some commenters request that the
Commission extend the compliance
date.78 For example, EEI requests that
the compliance date be at least one full
year after the Commission issues a Final
Rule and the EQR filing web interface is
pre-tested, corrected, and available for
general use before withdrawing the
current FoxPro-based software filing
option.79 EEI states that this time would
give companies a chance to test the new
web interface and iron out any problems
before the current FoxPro-based
software is no longer an option.80
39. As for the XML filing option,
commenters argue that it takes at least
12 months to develop and test software
to file in XML and to train staff on using
the software.81 Pacific Gas and Electric
states that software vendors cannot
design and offer products to customers
until they have a final XML schema
document.82 Pacific Gas and Electric
asserts that it is only after vendors make
their products available that customers
can evaluate and purchase products,
and begin retooling their internal
business processes to accommodate the
new EQR requirements.83 Thus, Pacific
Gas and Electric requests that the
Commission give regulated entities one
year from the date a Final Rule is
published in the Federal Register to
make the necessary internal data
collection changes and to acquire,
install, and test the software to file newsystem EQR submittals.84 Similarly, EEI
requests that the Commission provide a
full year after it issues a final XML Data
Structure and XML Data Values, holds
a technical conference to discuss the
XML filing option, and issues a Final
Rule in this proceeding before
withdrawing the current software.85
40. Several commenters assert that the
Commission should conclude any other
EQR-related rulemakings before
changing the EQR filing process so that
filers do not need to modify their system
77 NOPR,
FERC Stats. & Regs. ¶ 32,689 at P 11.
e.g., EEI at 8; Links Technology Solutions
at 2; Pacific Gas and Electric at 6.
79 EEI at 8.
80 EEI at 8.
81 See, e.g., EEI at 8; Pacific Gas and Electric at
6.
82 Pacific Gas and Electric at 6.
83 Pacific Gas and Electric at 6.
84 Pacific Gas and Electric at 6.
85 EEI at 8.
78 See,
74 See https://www.ferc.gov/docs-filing/
ferconline.asp.
75 We note that Commission staff does review
applications for a Company Identifier account and
that review can take up to several days.
76 See Order No. 2001–G, 120 FERC ¶ 61,270 at
PP 10–11 (‘‘the agent may be identified as the Seller
if the company’s tariff authorizes the agent to make
the sales.’’).
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multiple times.86 In addition, EEI also
states that the Commission will need to
keep the web interface and XML schema
up-to-date to accommodate any future
changes to the EQR, providing adequate
notice of such changes and time for EQR
filers and software vendors to adopt the
changes.87
41. EEI and Idaho Power recommend
that the Commission allow filers to file
their EQR in the current software and
proposed new web interface during the
transition period.88 Idaho Power
recommends that the Commission do so
for a minimum of two reporting periods
after the proposed implementation date
listed in the NOPR.89 EEI asserts that
this time would ensure that filers will
not be penalized because of problems
with the web interface or XML option.90
Idaho Power states that this grace period
will give filers time to transition, train,
and modify existing internal systems.91
In the alternative, Idaho Power
recommends and supports thorough
testing by a representative sample of
filers prior to the proposed
implementation date in the NOPR to
identify and correct system issues.92
42. Several commenters request that
the Commission hold a second technical
conference that includes a live
demonstration of the new filing
options.93 Idaho Power states that
Commission staff should provide a
thorough live demonstration of the
proposed web interface, including but
not limited to walking through the steps
of a complete start to finish EQR
filing.94 Energy Compliance Consulting
states that the demonstration should
show more completely how filers will
interact with the software and include
the submission of very large files and
files with numerous errors so that
prospective users will know how the
system will present those errors and
what the time will be compared to the
current EQR software.95 EEI states that
the demonstration should be available
by computers and should accommodate
questions and provide answers in real
time, similar to an EQR user group
conference call.96 Pacific Gas and
Electric requests that the Commission
86 See, e.g., EEI at 9–10; Energy Compliance
Consulting at 2; EPSA at 6, 9–10.
87 EEI at 10.
88 See, e.g., EEI at 9; Idaho Power at 3–4.
89 Idaho Power at 3.
90 EEI at 9.
91 Idaho Power at 3.
92 Id. at 4.
93 See, e.g., EEI at 6; Energy Compliance
Consulting at 4; Idaho Power at 4; Pacific Gas and
Electric at 9.
94 Idaho Power at 4.
95 Energy Compliance Consulting at 4.
96 EEI at 7.
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14:04 Nov 29, 2012
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schedule another technical conference
in the near future to further present
system functionalities and capabilities
because a Final Rule in this matter may
establish a level of certainty about the
technical functions and behavior of the
new system on both the server and
client side of the equation.97
43. EEI asserts that filers and vendors
may have questions about adopting the
structure and values for use in filing
EQR data in XML format.98 Therefore,
EEI encourages the Commission to hold
a conference call/meeting to discuss the
XML option only so that the
Commission can answer questions about
use of the data structure and values,
correct problems, and help avoid errors
in use of the option.99
44. Some commenters recommend
that the Commission work with
companies and software vendors to test
the proposed new web interface before
it goes public.100 EEI states that
problems may include missing
functions that the software currently
provides, inability to upload data
required in various columns or rows,
errors in how the web interface handles
data being uploaded, or unclear filing
instructions.101 EEI encourages the
Commission to ensure that the new web
interface is fully tested for anomalies
and corrected to remove problems
before it is made available for general
use.102 EEI offers to ask for volunteers
for this effort from among its
members.103
45. CAISO and Idaho Power state that,
based on the technical conference and
FAQ document, it appears as though the
copy forward function will not be
available for the initial Q3 2013 EQR
filing so that respondents will be
responsible for transferring all data to
the new web interface.104 CAISO and
Idaho Power assert that requiring
respondents to enter all of the preexisting data manually rather than
through an automated procedure would
be burdensome and strain filers’ time
and resources.105 Idaho Power requests
that the Commission develop an
automated method, or provide detailed
instructions on how to load or transfer
the existing data from the FoxPro
system into the new system for the
initial web interface filing.106 Similarly,
97 Pacific
Gas and Electric at 9.
at 7.
99 Id. at 7–8.
100 See, e.g., EEI at 6; Energy Compliance
Consulting at 5.
101 EEI at 6.
102 Id. at 5–6.
103 Id. at 6.
104 CAISO at 4; Idaho Power at 4.
105 CAISO at 3; Idaho Power at 4.
106 Idaho Power at 4.
98 EEI
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CAISO argues that the Commission
should be responsible for populating the
database that underlies the new web
interface with the data from the EQR
respondents’ Q2 2013 EQR.107 CAISO
asserts that the Commission already will
possess all of the data submitted by
respondents for Q2 2013 EQR, and thus
be better situated to perform the
necessary data transfer.108 CAISO also
asserts that it is concerned that errors
may be introduced into the data if the
process of incorporating previously
submitted data is made more
complicated than the current copy
forward method.109
46. EEI states that the proposed
changes to the regulatory text are too
ambiguous, particularly the reference to
‘‘as otherwise provided to the public’’
because it does not specify where and
how the Commission will provide such
guidance.110 EEI also suggests that the
Commission publish notices in the
Federal Register anytime the
Commission posts generally applicable
guidance or similar documents on the
Commission’s Web site to ensure that
the regulated community has prompt
and adequate notices of the new
information.111 Thus, EEI recommends
that the Commission modify the
proposed regulatory text to read,
‘‘Electric Quarterly Reports must be
prepared in conformance with
Commission guidance being published
in the Federal Register.’’ 112
3. Commission Determination
47. We direct EQR sellers to comply
with the changes to the process for filing
EQRs beginning with the Q3 2013 EQR,
providing data for July through
September 2013. We find that this time
period provides EQR sellers with
sufficient time to choose between the
two filing options, transition to the new
filing process, and file their Q3 2013
EQR in a timely manner. We disagree
with commenters that argue that EQR
sellers will need up to a year to adapt
to the new filing options. As explained
above,113 the web interface option will
operate similar to the current software
and should not require significant
changes to an EQR seller’s existing
internal system. An EQR seller that
would like to file using the XML option,
but is not prepared to do so by the filing
deadline for Q3 2013 EQR, can file
107 CAISO
at 3–4.
at 3.
109 Id. at 4–5.
110 EEI at 11.
111 Id. at 11–12.
112 Id. at 12.
113 See discussion supra section III.A.
108 Id.
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
through the web interface until it is able
to transition to the XML option.
48. Starting with Q3 of 2013, we will
no longer be able to accept EQR filings
submitted through the current EQR
software. In the Transparency Rule, the
Commission revised the EQR filing
requirements, adding some fields and
deleting others.114 Due to technical
limitations, the Commission cannot add
the new fields to the current EQR
software. Therefore, consistent with the
compliance deadline in the
Transparency Rule, EQR sellers must
file using the new filing process
beginning with Q3 of 2013.
49. As explained throughout this
Final Rule, the Commission will assist
EQR sellers and agents in transitioning
to the new filing process. The
Commission directs staff to hold
technical conferences to explain the
new filing process as needed. However,
the Commission will not offer a live
demonstration of the new EQR filing
options because the technology is still
in development and will not be
completed until after the rulemaking
process is complete.
50. The Commission cannot prepopulate the new filing Web interface
with Q2 2013 EQR data because the
Web interface will include new fields
that will not be present in the Q2 2013
EQR. However, we remind EQR sellers
and agents that the current EQR
software includes the ability to export a
CSV file. EQR sellers and agents can
export a CSV file from the EQR software
that companies could then use, after
revisions have been made to
accommodate new requirements, to
import into the new web-based system.
51. We agree with EEI that the
reference to ‘‘as otherwise provided to
the public’’ in the proposed regulatory
text is ambiguous. Accordingly, we have
removed that phrase from the regulatory
text adopted in this Final Rule, and
adopt text that states that ‘‘Electric
Quarterly Reports must be prepared in
conformance with the Commission’s
guidance posted on the FERC Web site
(https://www.ferc.gov).’’ We disagree
with EEI that the Commission should
wreier-aviles on DSK5TPTVN1PROD with
114 Transparency Rule, FERC Stats. & Regs.
¶ 31,336.
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14:04 Nov 29, 2012
Jkt 229001
publish a notice in the Federal Register
every time the Commission posts new
guidance on the Commission’s Web site.
The Commission publishes notices
when it proposes changes to existing
requirements, but we do not find it
necessary to publish a notice in the
Federal Register whenever the
Commission posts, for example, answers
to frequently asked questions.
IV. Information Collection Statement
52. The Office of Management and
Budget (OMB) requires that OMB
approve certain information collection
and data retention requirements
imposed by agency rules.115 Therefore,
the Commission is submitting the
proposed modifications to its
information collection statement to
OMB for review and approval in
accordance with section 3507(d) of the
Paperwork Reduction Act of 1995.116
53. OMB’s regulations require
approval of certain information
collection requirements imposed by
agency rules. Upon approval of a
collection(s) of information, OMB will
assign an OMB control number and an
expiration date. Respondents subject to
the filing requirements of a rule will not
be penalized for failing to respond to
these collections of information unless
the collections of information display a
valid OMB control number.
54. The Commission is submitting
these reporting requirements to OMB for
its review and approval under section
3507(d) of the Paperwork Reduction
Act. Comments were solicited on the
Commission’s need for this information;
whether the information will have
practical utility; the accuracy of
provided burden estimates; ways to
enhance the quality, utility, and clarity
of the information to be collected; and
any suggested methods for minimizing
the respondent’s burden, including the
use of automated information
techniques.117
55. Some commenters question the
Commission’s burden estimate.118
CFR 1320.11(b) (2010).
U.S.C. 3507(d) (2006).
117 NOPR, FERC Stats. & Regs. ¶ 32,689 at P 13.
118 See, e.g., Energy Compliance at 5; Pacific Gas
and Electric at 6.
Energy Compliance Consulting states
that there is no explanation of why a
utility’s membership in a regional
transmission organization (RTO) would
affect its filing burden.119 Energy
Compliance Consulting also states that
it is unclear whether the burden
estimate assumes how many, if any,
utilities will move to the new XML
format.120 Pacific Gas and Electric
asserts that the Commission’s burden
estimates fall short of the cost of
transitioning to the XML option.121
56. We find that a public utility’s
membership in an RTO or independent
transmission system operator (ISO)
should not affect the burden of
complying with the Final Rule.
Consequently, for this Final Rule, we
estimate that the one-time burden hours,
the recurring burden hours, and the
average annual burden hours will be the
same for all EQR sellers, irrespective of
membership in an RTO or ISO. We have
broken out EQR sellers by RTO/ISO
membership status simply to be
consistent with the way that the
Commission estimated the average
burden per respondent associated with
the existing EQR system in a separate
filing submitted to OMB.122
57. In the NOPR, the Commission
estimated the number of hours required
for public utilities to comply with the
minimum requirements included in the
NOPR. While public utilities may opt to
use the XML option, we consider the
move to the Web interface to be a less
burdensome option for public utilities
because it builds upon the automated
systems that they have developed to
enter data into the current EQR
software. Thus, the Commission’s
burden estimate did not estimate how
many public utilities will voluntarily
transition to the XML option or the
number of hours required for a public
utility to transition to the XML option.
58. The Commission’s estimates of the
average public reporting burden and
cost related to the proposed rule in
Docket RM12–3–000 are as follows:
115 5
116 44
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119 Energy
Compliance Consulting at 5.
Compliance Consulting at 5.
121 Pacific Gas and Electric at 6.
122 See NOPR, Stats. & Regs. ¶ 32,689 at n.17.
120 Energy
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71297
FINAL RULE IN RM12–3–000 ON ELECTRIC QUARTERLY REPORT
Number of
respondents
Companies within
non-California
RTO, and large
cos. within Cal.
RTO.
Medium/small
companies within Cal. RTO.
Companies not
within RTO.
Companies with no
transactions.
Sub-Total—All
Public Utilities
(Existing Filers).
Non Public Utilities
(New Filers).
Total—All Utilities.
Number of
responses
per
respondent
per year
Implementing (one-time) burden
per respondent
Burden hours
wreier-aviles on DSK5TPTVN1PROD with
Burden hours 124
Cost ($)
Burden hours
405
4
20
$1,434.50
no change ..........
no change ..........
6.67 ....................
$478.17.
20
4
20
$1,434.50
no change ..........
no change ..........
6.67 ....................
$478.17.
663
4
20
$1,434.50
no change ..........
no change ..........
6.67 ....................
$478.17.
695
4
20
$1,434.50
no change ..........
no change ..........
6.67 ....................
$478.17.
1,783
4
35,660
$2,557,713.50
no change ..........
no change ..........
11,892.61 ...........
$852,577.11.
53
4
........................
........................
no change ..........
no change ..........
no change ..........
no change.
1,836
4
35,660
$2,557,713.50
no change ..........
no change ..........
11,892.61 ...........
$852,577.11.
59. The total estimated one-time
implementation burden and cost for all
respondents is 35,660 hours (1,783 × 20
hours), and $2,557,713.50 (1,783 ×
$1,434.50). Averaging this one-time
implementation burden and cost over
Years 1–3 yields an annual total burden
of 11,892.61 hours (1,783 × 6.67) and an
annual total cost of $852,577.11 (1,783
× $478.17)
60. We recognize that there will be an
initial implementation burden for
current EQR sellers (filers) associated
with reviewing instructions, revising
filing process, obtaining a Company
Identifier, designating an agent(s), and
filing EQR data through the new system.
We estimate a burden of 20 hours per
existing respondent for this one-time,
initial implementation burden. The
Transparency Rule requires non-public
utilities to file EQRs for the first time in
Q3 of 2013, consistent with the
implementation date of this Final
Rule.125 Non-public utilities will file for
123 The Commission expects no change or a slight
decrease in the Recurring Operating Burden per
Respondent per Response under the new filing
system (when compared to quarterly filings for
current filers under the existing system).
124 For the current EQR software and reporting
requirements, the Commission estimates the
average burden per respondent per quarterly filing
to be: 32 hours for Companies within non-California
RTO, and large companies within the California
RTO; 80 hours for medium/small Companies within
the California RTO; 3 hours for Companies not
within an RTO; and 0.083 hours [5 minutes] for
Companies with no transactions.
125 Transparency Rule, FERC Stats. & Regs. ¶ a P
31,336. The burden on non-public utilities
associated with filing EQRs was captured in the
Transparency Rule. In the Transparency Rule, the
Commission estimated per non-public utility 400
hours for one-time implementation, and 19 hours
for recurring burden for each quarterly filing. The
estimated average annual burden per non-public
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Cost ($)
Average annual burden per
respondent (implementation
averaged over years 1–3)
Recurring operating burden per
respondent per
response 123
16:20 Nov 29, 2012
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Cost ($)
the first time using the new filing
options and will not need to transition
from the current EQR software.
Therefore, we estimate no change for
non-public utilities.
61. To help with the implementation
of this Final Rule, we will direct
Commission staff to convene a staff-led
technical conference for industry
participants to demonstrate the two new
options for filing EQRs. The conference
will be available by webcast, which
should minimize travel and other costs
associated with participation in the
conference. We will also direct staff to
assist in transitioning to the new
process. Commission staff’s technical
conference and assistance should
minimize the initial implementation
burden.
62. For the recurring effort involved
in electronically submitting EQR data
on a quarterly basis to the Commission,
we anticipate that there will be no
change or a slight burden reduction for
current filers compared to the burden of
making quarterly filings under the
current system.
Information Collection Costs: We
estimate the cost of compliance per
existing respondent will be $1,434.50,
for one-time implementation of the
changes proposed in this Final Rule. We
estimate that the implementation costs
will be as follows: 126
• Legal staff (at $250/hour), for 2
hours, costing $500
• Senior accountant (at $51.38/hr.),
financial analyst (at $68.12/hr.), and/or
support staff (at $35.99/hr.), averaged at
$51.83/hr., for a total of 2 hours, costing
$103.66
• Information technology analyst (at
$57.24/hour), for 12 hours, costing
$686.88
• Support staff (at $35.99/hr), for 4
hours, costing $143.96.
TITLE: FERC–920,127 Electric
Quarterly Report, OMB Control No.
1902–0255.
Action: Proposed new EQR filing
system and associated additional
reporting requirements.
Respondents: Electric utilities.
Frequency of Responses: Initial
implementation and quarterly filings
(beginning Q3 of 2013).
Need For Information: We are
implementing changes to the method for
filing EQRs. We are replacing a filing
system that requires the use of
Commission software with a system that
would allow an EQR seller to file EQR
data directly through the Commission’s
Web site, either through a Web interface
or by submitting an XML-formatted file.
We are also requiring the EQR seller to
identify itself with a Company Identifier
that will be assigned through the
Commission’s Company Registration
System.
utility (with implementation averaged over Years 1–
3) was 209.33 hours.
126 Hourly average wage is an average and was
calculated using Bureau of Labor Statistics (BLS),
Occupational Employment Statistics data for May
2011 (for NAICS 221100—Electric Power
Generation, Transmission and Distribution, at
https://bls.gov/oes/current/naics4_221100.htm#000000) for the senior accountant, financial analyst,
information technology analyst, and support staff.
The average hourly figure for legal staff is a
composite from BLS and other resources.
127 The Commission is separating the EQR
reporting requirements from the remaining
reporting requirements under FERC–516 (Electric
Rate Schedules and Tariff Filings, OMB Control No.
1902–0096). After implementation of this Final
Rule and issuance of an OMB decision, the EQR
burden figures will be removed from FERC–516.
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
Internal Review: We have reviewed
the changes and determined that the
changes are necessary. These
requirements conform to the
Commission’s need for efficient
information collection, communication,
and management within the energy
industry. We have assured ourselves, by
means of internal review, that there is
specific, objective support for the
burden estimates associated with the
information collection requirements.
63. Interested persons may obtain
information on the reporting
requirements by contacting: Federal
Energy Regulatory Commission, 888
First Street NE., Washington, DC 20426
[Attention: Ellen Brown, Office of the
Executive Director, email:
DataClearance@ferc.gov, Phone: (202)
502–8663, fax: (202) 273–0873].
Comments on the requirements of this
rule may also be sent to the Office of
Information and Regulatory Affairs,
Office of Management and Budget,
Washington, DC 20503 [Attention: Desk
Officer for the Federal Energy
Regulatory Commission]. For security
reasons, comments should be sent by
email to OMB at
oira_submission@omb.eop.gov. Please
reference OMB Control No. 1902–0255,
FERC–920, and Docket No. RM12–3 in
your submission.
V. Environmental Analysis
64. The Commission is required to
prepare an Environmental Assessment
or an Environmental Impact Statement
for any action that may have a
significant adverse effect on the human
environment.128 The actions taken here
fall within categorical exclusions in the
Commission’s regulations for
information gathering, analysis, and
dissemination.129 Therefore, an
environmental assessment is
unnecessary and has not been prepared
in this rulemaking.
wreier-aviles on DSK5TPTVN1PROD with
VI. Regulatory Flexibility Act
65. The Regulatory Flexibility Act of
1980 (RFA) 130 generally requires a
description and analysis of final rules
that will have significant economic
impact on a substantial number of small
entities. The RFA mandates
consideration of regulatory alternatives
that accomplish the stated objectives of
a proposed rule and that minimize any
significant economic impact on a
substantial number of small entities.
The SBA’s Office of Size Standards
128 Regulations Implementing the National
Environmental Policy Act, Order No. 486, 52 FR
47897 (Dec. 17, 1987), FERC Stats. & Regs.
Preambles 1986–1990 ¶ 30,783 (1987).
129 18 CFR 380.4(a)(5).
130 5 U.S.C. 601–612.
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14:04 Nov 29, 2012
Jkt 229001
develops the numerical definition of a
small business.131 The SBA has
established a size standard for electric
utilities, stating that a firm is small if,
including its affiliates, it is primarily
engaged in the transmission, generation
and/or distribution of electric energy for
sale and its total electric output for the
preceding twelve months did not exceed
4,000,000 MWh.132
66. As discussed in Order No.
2000,133 in making this determination,
the Commission is required to examine
only the direct compliance costs that a
rulemaking imposes upon small
businesses. It is not required to consider
indirect economic consequences, nor is
it required to consider costs that an
entity incurs voluntarily.
67. For non-public utilities, the
Commission exempts under the de
minimis market presence threshold nonpublic utilities that make 4,000,000
MWh or less of annual wholesale sales
(based on an average of the wholesale
sales it made in the preceding three
years).134 This de minimis threshold
excludes small, non-public utilities.
Therefore, this Final Rule will not have
a significant economic impact on any
small, non-public utility.
68. For public utilities, based on
analysis of the EQR filings made in the
four quarters of 2011, there are 1,783
entities that currently file an EQR, but
given clearly identifiable affiliate
relationships that number is reduced to
1,215 entities. Of those, 97 reported
more than 4,000,000 MWh of wholesale
sales in the EQR. Of the remaining 1,118
entities that reported less than 4,000,000
MWh of wholesales sales in the EQR,
641 filed transactions in the EQR. The
rest that would be subject to this Final
Rule, 477 entities, did not file
transactions in any quarter of 2011; we
conclude that this Final Rule will
minimally affect them.
69. As for the remaining 641 entities,
we note that there are two types of
companies among those currently filing
EQRs that merit additional
131 13
CFR 121.101.
CFR 121.201, Sector 22, Utilities & n.1.
133 See Regional Transmission Organizations,
Order No. 2000, 65 FR 809 (Jan. 6, 2000), FERC
Stats. & Regs. ¶ 31,089, at 31,237 & n.754 (1999),
order on reh’g, Order No. 2000–A, 65 FR 12,088
(Mar. 8, 2000), FERC Stats. & Regs. ¶ 31,092 (2000),
aff’d sub nom. Pub. Util. Dist. No. 1 of Snohomish,
County Washington v. FERC, 272 F.3d 607, 348 U.S.
App. DC 205 (DC Cir. 2001) (citing Mid-Tex Elec.
Coop. v. FERC, 773 F.2d 327 (DC Cir. 1985)
(Commission need only consider small entities
‘‘that would be directly regulated’’); Colorado State
Banking Bd. v. RTC, 926 F.2d 931 (10th Cir. 1991)
(Regulatory Flexibility Act not implicated where
regulation simply added an option for affected
entities and did not impose any costs)).
134 Transparency Rule, FERC Stats. & Regs.
¶ 31,336 at P 54.
132 13
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consideration. First, there are investorowned public utilities that make both
wholesale and retail sales. The SBA’s
definition of a small utility is based on
a utility’s total electric output for the
preceding twelve months, which
includes a public utility’s retail sales.
However, our estimate in this section is
based on information available in the
EQR, which includes annual wholesale
sales but not retail sales. If we were able
to include retail sales, we believe that
most investor-owned public utilities
that currently file EQRs make more than
4,000,000 MWh annual wholesale and
retail sales and thus would not be
classified as small. Second, there are
power marketers that often do not own
or control generation or transmission
and may be affiliated with companies
that are not primarily engaged in the
sale of electric energy (such as financial
institutions or hedge funds).135
However, information regarding
whether a power marketer is affiliated
with another company is generally not
included in an EQR filing, making it
difficult to determine the number of
small entities that are affiliated with a
larger company, thereby leading to an
inflated estimate of the number of
companies affected by this Final Rule
that are truly small.
70. Furthermore, to ease the burden of
implementation for all EQR sellers, we
will minimize the changes which EQR
sellers will experience because the
Commission is adopting two options for
filing EQRs: the Web interface and XML.
The estimated one-time implementation
cost per EQR seller is $1,434.50. We
anticipate no change or a slight
reduction in the burden for the
recurring quarterly EQR filings. In
addition, small entities generally have
few or no transactions and
corresponding minimal recurring
burden. We note that EQR sellers may
request, on an individual basis, waiver
from the Commission’s EQR reporting
requirements. Thus, we certify that this
proposed rule will not have a significant
impact on a substantial number of small
entities.
VII. Document Availability
71. 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
FERC’s Home Page (https://www.ferc.gov)
and in FERC’s Public Reference Room
135 Some of these such as Google, Occidental
Chemical and ONEOK may not qualify as small in
their primary area of business and are participating
in the electric market as part of an overall corporate
strategy.
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during normal business hours (8:30 a.m.
to 5:00 p.m. Eastern time) at 888 First
Street NE., Room 2A, Washington DC
20426.
72. From FERC’s Home Page on the
Internet, this information is available on
eLibrary. The full text of this document
is available on eLibrary in PDF and
Microsoft Word format for viewing,
printing, and/or downloading. To access
this document in eLibrary, type the
docket number excluding the last three
digits of this document in the docket
number field.
73. User assistance is available for
eLibrary and the FERC’s Web site during
normal business hours from FERC
Online Support at (202) 502–6652 (toll
free at 1–866–208–3676) or email at
ferconlinesupport@ferc.gov, or the
Public Reference Room at (202) 502–
8371, TTY (202) 502–8659. Email the
Public Reference Room at
public.referenceroom@ferc.gov.
VIII. Effective Date and Congressional
Notification
74. These regulations are effective
April 1, 2013. The Commission has
determined, with the concurrence of the
Administrator of the Office of
Information and Regulatory Affairs of
OMB, that this rule is not a ‘‘major rule’’
as defined in section 351 of the Small
Business Regulatory Enforcement
Fairness Act of 1996.
71299
PART 35—FILIING OF RATE
SCHEDULES AND TARIFFS
1. The authority citation for Part 35
continues to read as follows:
■
Authority: 16 U.S.C. 791a–825r, 2601–
2645; 31 U.S.C. 9701; 42 U.S.C. 7101–7352.
2. Section 35.10b is amended by
revising the second sentence to read as
follow:
■
List of Subjects in 18 CFR Part 35
§ 35.10b
Electric power rates, Electric utilities,
Reporting and recordkeeping
requirements.
* * * Electric Quarterly Reports must
be prepared in conformance with the
Commission’s guidance posted on the
FERC Web site (https://www.ferc.gov).
NOTE: The following appendices A
and B will not appear in the Code of
Federal Regulations:
By direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
Electric Quality Reports.
In consideration of the foregoing, the
Commission amends 18 CFR part 35 as
follows:
APPENDIX A: ABBREVIATED NAMES OF COMMENTERS
Commenters
Abbreviation
California Independent System Operator Corporation .............................
Edison Electric Institute ............................................................................
Electric Power Supply Association ...........................................................
Energy Compliance Consulting, LLC .......................................................
Energy Services Providers, Inc., ..............................................................
Connecticut Gas & Electric, Inc., and Massachusetts Gas & Electric
Inc..
Idaho Power Company .............................................................................
Links Technology ......................................................................................
Solutions, Inc. ...........................................................................................
Pacific Gas and Electric Company ...........................................................
Southern California Edison Company ......................................................
CAISO
EEI
EPSA
Energy Compliance Consulting
Energy Services Providers
Idaho Power
Links
Technology Solutions
Pacific Gas and Electric
Southern California Edison
Appendix B: EQR Data Dictionary
Electric Quarterly Report Data Dictionary
Version 2.1 (issued November 15, 2012) 136
EQR DATA DICTIONARY
Field No.
Field
Old
Required
Value
Definition
New
ID Data
wreier-aviles on DSK5TPTVN1PROD with
1 .........
1 .......
Filer Unique Identifier ..
✓ ..................................
136 This version of Appendix B replaces the
version that was included with Revisions to Electric
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FS# (where ‘‘#’’ is an
integer).
(Seller)—An identifier (e.g., ‘‘FS1’’, ‘‘FS2’’)
used to designate a record containing Seller
identification information in a comma-delimited (csv) file that is imported into the EQR
filing. One record for each seller company
may be imported into an EQR for a given
quarter.
Quarterly Report Filing Process, Order No. 770, 141
FERC ¶ 61,120 (2012).
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
EQR DATA DICTIONARY—Continued
Field No.
Field
Required
Value
Definition
1 .......
Filer Unique Identifier ..
✓ ..................................
FA1 ..............................
2 .........
2 .......
Company Name ...........
✓ ..................................
Unrestricted text (100
characters).
2 .........
2 .......
Company Name ...........
✓ ..................................
Unrestricted text (100
characters).
(Agent)—An identifier (i.e., ‘‘FA1’’) used to designate a record containing Agent identification information in a comma-delimited (csv)
file that is imported into the EQR filing. Only
one record with the FA1 identifier may be
imported into an EQR for a given quarter.
(Seller)—The name of the company that is authorized to make sales as indicated in the
company’s FERC tariff(s).
(Agent)—The name of the entity completing
the EQR filing. The Agent’s Company Name
need not be the name of the company under
Commission jurisdiction.
3 .........
............
X .......
3 .......
......................................
Company Identifier ......
......................................
✓ ..................................
3 .........
4 .......
Contact Name ..............
✓ ..................................
......................................
A 7-digit integer proceeded by the letter
‘‘C’’.
Unrestricted text (50
characters).
3 .........
4 .......
Contact Name ..............
✓ ..................................
4 .........
5 .......
Contact Title ................
✓ ..................................
5 .........
6 .......
Contact Address ..........
✓ ..................................
6 .........
7 .......
Contact City .................
✓ ..................................
7 .........
8 .......
Contact State ...............
✓ ..................................
8 .........
9 .......
Contact Zip ..................
✓ ..................................
9 .........
10 .....
Contact Country Name
✓ ..................................
10 .......
11 .....
Contact Phone .............
✓ ..................................
11 .......
12 .....
Contact E-Mail .............
✓ ..................................
12 .......
13 .....
Transactions Reported
to Index Price Publisher(s).
✓ ..................................
Y (Yes) .........................
N (No)
13 .......
14 .....
Filing Quarter ...............
✓ ..................................
YYYYMM .....................
Old
New
1 .........
Unrestricted text (50
characters).
Unrestricted text (50
characters).
Unrestricted text ..........
Unrestricted text (30
characters).
Unrestricted text (2
characters).
Unrestricted text (10
characters).
CA—Canada ................
MX—Mexico
US—United States
UK—United Kingdom
Unrestricted text (20
characters).
Unrestricted text ..........
(Seller)—Identifier obtained through the Commission’s Company Registration system.
(Seller)—The name of the contact for the company authorized to make sales as indicated
in the company’s FERC tariff(s).
(Agent)—Name of the contact for the Agent,
usually the person who prepares the filing.
Title of contact identified in Field Number 4.
Street address for contact identified in Field
Number 4.
City for the contact identified in Field Number
4.
Two character state or province abbreviations
for the contact identified in Field Number 4.
Zip code for the contact identified in Field
Number 4.
Country (USA, Canada, Mexico, or United
Kingdom) for contact address identified in
Field Number 4.
Phone number of contact identified in Field
Number 4.
E-mail address of contact identified in Field
Number 4.
Filers should indicate whether they have reported their sales transactions to index price
publisher(s). If they have, filers should indicate specifically which index publisher(s) in
Field Number 73.
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).
EQR Data Dictionary Contract Data
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14 .......
15 .....
Contract Unique ID ......
✓ ..................................
15 .......
16 .....
Seller Company Name
✓ ..................................
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An integer proceeded
An identifier beginning with the letter ‘‘C’’ and
by the letter ‘‘C’’
followed by a number (e.g., ‘‘C1’’, ‘‘C2’’)
(only used when imused to designate a record containing conporting contract data).
tract 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.
Unrestricted text (100
The name of the company that is authorized to
characters).
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).
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71301
EQR DATA DICTIONARY—Continued
Field No.
Field
Required
Value
✓ ..................................
X .......
18 .....
Customer Company
Name.
......................................
Contract Affiliate ..........
......................................
✓ ..................................
Unrestricted text (70
characters).
......................................
Y (Yes) .........................
N (No)
18 .......
19 .....
FERC Tariff Reference
✓ ..................................
Unrestricted text (60
characters).
19 .......
20 .....
Contract Service
Agreement ID.
✓ ..................................
Unrestricted text (30
characters).
20 .......
21 .....
Contract Execution
Date.
✓ ..................................
YYYYMMDD ................
21 .......
22 .....
Commencement Date
of Contract Terms.
✓ ..................................
YYYYMMDD ................
22 .......
23 .....
24 .....
If specified in the contract.
If contract terminated ...
YYYYMMDD ................
23 .......
YYYYMMDD ................
The date the contract actually terminates.
24 .......
25 .....
✓ ..................................
Unrestricted text ..........
25 .......
25 .......
26 .....
26 .....
Contract Termination
Date.
Actual Termination
Date Extension.
Extension Provision
Description.
Class Name .................
Class Name .................
The customer is an affiliate if it controls, is controlled by or is under common control with
the seller. This includes a division that operates as a functional unit. A customer of a
seller who is an Exempt Wholesale Generator may be defined as an affiliate under the
Public Utility Holding Company Act and the
FPA.
The FERC tariff reference cites the document
that specifies the terms and conditions under
which a Seller is authorized to make transmission sales, power sales or sales of related jurisdictional services at cost-based
rates or at market-based rates. If the sales
are market-based, the tariff that is specified
in the FERC order granting the Seller Market
Based Rate Authority must be listed.
Unique identifier given to each service agreement that can be used by the filing company
to produce the agreement, if requested. The
identifier may be the number assigned by
FERC for those service agreements that
have been filed with and accepted by the
Commission, or it may be generated as part
of an internal identification system.
The date the contract was signed. If the parties
signed on different dates, use the most recent date signed.
The date the terms of the contract reported in
fields 18, 23 and 25 through 44 (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 44 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.
The date that the contract expires.
✓ ..................................
✓ ..................................
......................................
F—Firm ........................
25 .......
26 .....
Class Name .................
✓ ..................................
NF—Non-firm ...............
Description of terms that provide for the continuation of the contract.
See definitions of each class name below.
For transmission sales, a service or product
that always has priority over non-firm service. For power sales, a service or product
that is not interruptible for economic reasons.
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.
17 .....
17 .......
17 .......
Definition
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16 .......
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The name of the counterparty.
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71302
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EQR DATA DICTIONARY—Continued
Field No.
Field
Required
Value
Definition
26 .....
Class Name .................
✓ ..................................
UP—Unit Power Sale ..
25 .......
26 .....
Class Name .................
✓ ..................................
N/A—Not Applicable ....
26 .......
27 .....
Term Name ..................
✓ ..................................
27 .......
27 .......
28 .....
28 .....
Increment Name ..........
Increment Name ..........
✓ ..................................
✓ ..................................
LT—Long Term ...........
ST—Short Term
N/A—Not Applicable
......................................
H—Hourly ....................
27 .......
28 .....
Increment Name ..........
✓ ..................................
D—Daily .......................
27 .......
28 .....
Increment Name ..........
✓ ..................................
W—Weekly ..................
27 .......
28 .....
Increment Name ..........
✓ ..................................
M—Monthly ..................
27 .......
28 .....
Increment Name ..........
✓ ..................................
Y—Yearly .....................
27 .......
28 .....
Increment Name ..........
✓ ..................................
N/A—Not Applicable ....
28 .......
29 .....
✓ ..................................
......................................
28 .......
29 .....
Increment Peaking
Name.
Increment Peaking
Name.
✓ ..................................
FP—Full Period ...........
28 .......
29 .....
Increment Peaking
Name.
✓ ..................................
OP—Off-Peak ..............
28 .......
29 .....
Increment Peaking
Name.
✓ ..................................
P—Peak .......................
28 .......
29 .....
✓ ..................................
N/A—Not Applicable ....
29 .......
29 .......
30 .....
30 .....
Increment Peaking
Name.
Product Type Name ....
Product Type Name ....
✓ ..................................
✓ ..................................
......................................
CB—Cost Based .........
29 .......
30 .....
Product Type Name ....
✓ ..................................
CR—Capacity Reassignment.
29 .......
30 .....
Product Type Name ....
✓ ..................................
MB—Market Based .....
29 .......
30 .....
Product Type Name ....
✓ ..................................
T—Transmission ..........
29 .......
30 .....
Product Type Name ....
✓ ..................................
Other ............................
30 .......
31 .....
Product Name ..............
✓ ..................................
31 .......
32 .....
Quantity .......................
32 .......
33 .....
Units .............................
33 .......
34 .....
Rate .............................
34 .......
35 .....
Rate Minimum .............
35 .......
36 .....
Rate Maximum ............
If specified in the contract.
If specified in the contract.
One of four rate fields
(34, 35, 36, or 37)
must be included.
One of four rate fields
(34, 35, 36, or 37)
must be included.
One of four rate fields
(34, 35, 36, or 37)
must be included.
See Product Name
Table, Appendix A.
Number with up to 4
decimals.
See Units Table, Appendix E.
Number with up to 4
decimals.
Designates a dedicated sale of energy and capacity from one or more than one specified
generation unit(s).
To be used only when the other available
Class Names do not apply.
Contracts with durations of one year or greater
are long-term. Contracts with shorter durations are short-term.
See definitions for each increment below.
Terms of the contract (if specifically noted in
the contract) set for up to 6 consecutive
hours (≤ 6 consecutive hours).
Terms of the contract (if specifically noted in
the contract) set for more than 6 and up to
60 consecutive hours (>6 and ≤ 60 consecutive hours).
Terms of the contract (if specifically noted in
the contract) set for over 60 consecutive
hours and up to 168 consecutive hours (>60
and ≤ 168 consecutive hours).
Terms of the contract (if specifically noted in
the contract) set for more than 168 consecutive hours up to, but not including, one year
(>168 consecutive hours and < 1 year).
Terms of the contract (if specifically noted in
the contract) set for one year or more (≥ 1
year).
Terms of the contract do not specify an increment.
See definitions for each increment peaking
name below.
The product described may be sold during
those hours designated as on-peak and offpeak in the NERC region of the point of delivery.
The product described may be sold only during
those hours designated as off-peak in the
NERC region of the point of delivery.
The product described may be sold only during
those hours designated as on-peak in the
NERC region of the point of delivery.
To be used only when the increment peaking
name is not specified in the contract.
See definitions for each product type below.
Energy or capacity sold under a FERC-approved cost-based rate tariff.
An agreement under which a transmission provider sells, assigns or transfers all or portion
of its rights to an eligible customer.
Energy or capacity sold under the seller’s
FERC-approved market-based rate tariff.
The product is sold under a FERC-approved
transmission tariff.
The product cannot be characterized by the
other product type names.
Description of product being offered.
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Quantity for the contract product identified.
Measure stated in the contract for the product
sold.
The charge for the product per unit as stated in
the contract.
Number with up to 4
decimals.
Minimum rate to be charged per the contract, if
a range is specified.
Number with up to 4
decimals.
Maximum rate to be charged per the contract,
if a range is specified.
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71303
EQR DATA DICTIONARY—Continued
Field No.
Field
Required
Value
37 .....
Rate Description ..........
One of four rate fields
(34, 35, 36, or 37)
must be included.
37 .......
38 .....
Rate Units ....................
38 .......
39 .....
Point of Receipt Balancing Authority
(PORBA).
If specified in the contract.
If specified in the contract.
39 .......
40 .....
Point of Receipt Specific Location
(PORSL).
If specified in the contract.
40 .......
41 .....
Point of Delivery Balancing Authority
(PODBA).
If specified in the contract.
41 .......
42 .....
Point of Delivery Specific Location
(PODSL).
If specified in the contract.
42 .......
43 .....
Begin Date ...................
43 .......
44 .....
End Date ......................
45 .......
X .......
......................................
If specified in the contract.
If specified in the contract.
......................................
Definition
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36 .......
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Unrestricted text ..........
Text description of rate. If the rate is currently
available on the FERC Web site, a citation of
the FERC Accession Number and the relevant FERC tariff including page number or
section may be included instead of providing
the entire rate algorithm. If the rate is not
available on the FERC Web site, include the
rate algorithm, if rate is calculated. If the algorithm would exceed the 150 character field
limit, it may be provided in a descriptive
summary (including bases and methods of
calculations) with a detailed citation of the
relevant FERC tariff including page number
and section. If more than 150 characters are
required, the contract product may be repeated in a subsequent line of data until the
rate is adequately described.
See Rate Units Table,
Measure stated in the contract for the product
Appendix F.
sold.
See Balancing AuthorThe registered NERC Balancing Authority (fority Table, Appendix B.
merly 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.
Unrestricted text (50
The specific location at which the product is recharacters). If ‘‘HUB’’
ceived if designated in the contract. If receipt
is selected for
occurs at a trading hub, a standardized hub
PORCA, see Hub
name must be used. If more points of receipt
Table, Appendix C.
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.
See Balancing AuthorThe registered NERC Balancing Authority (fority Table, Appendix B.
merly called NERC Control Area) where a jurisdictional product is delivered and/or service ends for a transmission or transmissionrelated 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.
Unrestricted text (50
The specific location at which the product is
characters). If ‘‘HUB’’
delivered if designated in the contract. If reis selected for
ceipt occurs at a trading hub, a standardized
PODCA, see Hub
hub name must be used.
Table, Appendix C.
YYYYMMDDHHMM ..... First date for the sale of the product at the rate
specified.
YYYYMMDDHHMM ..... Last date for the sale of the product at the rate
specified.
......................................
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
EQR DATA DICTIONARY—Continued
Field No.
Field
Old
Required
Value
Definition
New
Transaction Data
45 .....
Transaction Unique ID
✓ ..................................
An integer proceeded
by the letter ‘‘T’’ (only
used when importing
transaction data).
45 .......
46 .....
Seller Company Name
✓ ..................................
Unrestricted text (100
Characters).
46 .......
47 .....
X .......
48 .....
Customer Company
Name.
......................................
FERC Tariff Reference
✓ ..................................
49 .......
47 .......
......................................
✓ ..................................
Unrestricted text (70
Characters).
......................................
Unrestricted text (60
Characters).
48 .......
49 .....
Contract Service
Agreement ID.
✓ ..................................
Unrestricted text (30
Characters).
49 .......
50 .....
51 .....
Transaction Unique
Identifier.
Transaction Begin Date
✓ ..................................
50 .......
51 .......
52 .....
Transaction End Date ..
✓ ..................................
52 .......
53 .....
Trade Date ...................
✓ ..................................
53 .......
54 .....
Exchange/Brokerage
Service.
......................................
Unrestricted text (24
Characters).
YYYYMMDDHHMM
(csv import);
MMDDYYYYHHMM
(manual entry).
YYYYMMDDHHMM
(csv import);
MMDDYYYYHHMM
(manual entry).
YYYYMMDD (csv import); MMDDYYYY
(manual entry).
See Exchange/Brokerage Service Table,
Appendix H.
54 .......
54 .......
54 .......
55 .....
55 .....
55 .....
Type of Rate ................
Type of Rate ................
Type of Rate ................
✓ ..................................
✓ ..................................
✓ ..................................
54 .......
55 .....
Type of Rate ................
✓ ..................................
54 .......
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44 .......
55 .....
Type of Rate ................
✓ ..................................
55 .......
56 .....
Time Zone ...................
✓ ..................................
56 .......
57 .....
Point of Delivery Balancing Authority
(PODBA).
✓ ..................................
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An identifier beginning with the letter ‘‘T’’ and
followed by a number (e.g., ‘‘T1’’, ‘‘T2’’) used
to designate a record containing transaction
information in a comma-delimited (csv) file
that is imported into the EQR filing. One
record for each transaction record may be
imported into an EQR for a given quarter. A
new transaction record must be used every
time a price changes in a sale.
The name of the company that is authorized to
make sales as indicated in the company’s
FERC tariff(s). This name must match the
name provided as a Seller’s ‘‘Company
Name’’ in Field 2 of the ID Data (Seller
Data).
The name of the counterparty.
The FERC tariff reference cites the document
that specifies the terms and conditions under
which a Seller is authorized to make transmission sales, power sales or sales of related jurisdictional services at cost-based
rates or at market-based rates. If the sales
are market-based, the tariff that is specified
in the FERC order granting the Seller Market
Based Rate Authority must be listed.
Unique identifier given to each service agreement that can be used by the filing company
to produce the agreement, if requested. The
identifier may be the number assigned by
FERC for those service agreements that
have been filed and approved by the Commission, or it may be generated as part of an
internal identification system.
Unique reference number assigned by the seller for each transaction.
First date and time the product is sold during
the quarter.
Last date and time the product is sold during
the quarter.
The date upon which the parties made the legally binding agreement on the price of a
transaction.
If a broker service is used to consummate or
effectuate a transaction, the term ‘‘Broker’’
shall be selected from the Commission-provided list. If an exchange is used, the specific exchange that is used shall be selected
from the Commission-provided list.
...................................... See type of rate definitions below.
Fixed ............................ A fixed charge per unit of consumption.
Formula ........................ A calculation of a rate based upon a formula
that does not contain an index component.
Electric Index ............... A calculation of a rate based upon an index or
a formula that contains an index component.
RTO/ISO ...................... A rate that is based on an RTO/ISO published
price or formula that contains an RTO/ISO
price component.
See Time Zone Table,
The time zone in which the sales will be made
Appendix D.
under the contract.
See Balancing AuthorThe registered NERC Balancing Authority (fority Table, Appendix B.
merly called NERC Control Area) abbreviation used in OASIS applications.
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71305
EQR DATA DICTIONARY—Continued
Field No.
Field
Required
Value
Definition
Point of Delivery Specific Location
(PODSL).
✓ ..................................
The specific location at which the product is
delivered. If receipt occurs at a trading hub,
a standardized hub name must be used.
59 .....
59 .....
Class Name .................
Class Name .................
✓ ..................................
✓ ..................................
Unrestricted text (50
characters). If ‘‘HUB’’
is selected for
PODBA, see Hub
Table, Appendix C.
......................................
F—Firm ........................
58 .......
59 .....
Class Name .................
✓ ..................................
NF—Non-firm ...............
58 .......
59 .....
Class Name .................
✓ ..................................
UP—Unit Power Sale ..
58 .......
59 .....
Class Name .................
✓ ..................................
BA—Billing Adjustment
58 .......
59 .....
Class Name .................
✓ ..................................
59 .......
60 .....
Term Name ..................
✓ ..................................
N/A—Not Applicable;
LT—Long Term.
ST—Short Term; N/A—
Not Applicable.
60 .......
60 .......
61 .....
61 .....
Increment Name ..........
Increment Name ..........
✓ ..................................
✓ ..................................
......................................
H—Hourly ....................
60 .......
61 .....
Increment Name ..........
✓ ..................................
D—Daily .......................
60 .......
61 .....
Increment Name ..........
✓ ..................................
W—Weekly ..................
60 .......
61 .....
Increment Name ..........
✓ ..................................
M—Monthly ..................
60 .......
61 .....
Increment Name ..........
✓ ..................................
Y—Yearly .....................
60 .......
61 .....
Increment Name ..........
✓ ..................................
N/A—Not Applicable ....
61 .......
62 .....
✓ ..................................
......................................
61 .......
62 .....
✓ ..................................
FP—Full Period ...........
61 .......
62 .....
Increment Peaking
Name.
Increment Peaking
Name.
Increment Peaking
Name.
✓ ..................................
OP—Off-Peak ..............
61 .......
62 .....
Increment Peaking
Name.
✓ ..................................
P—Peak .......................
61 .......
62 .....
✓ ..................................
N/A—Not Applicable ....
62 .......
63 .....
Increment Peaking
Name.
Product Name ..............
✓ ..................................
63 .......
64 .....
Transaction Quantity ...
✓ ..................................
See Product Names
Table, Appendix A.
Number with up to 4
decimals.
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57 .......
58 .....
58 .......
58 .......
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See class name definitions below.
A sale, service or product that is not interruptible for economic reasons.
A sale for which delivery or receipt of the energy may be interrupted for any reason or no
reason, without liability on the part of either
the buyer or seller.
Designates a dedicated sale of energy and capacity from one or more than one specified
generation unit(s).
Designates an incremental material change to
one or more transactions due to a change in
settlement results. ‘‘BA’’ may be used in a
refiling after the next quarter’s filing is due to
reflect the receipt of new information. It may
not be used to correct an inaccurate filing.
To be used only when the other available class
names do not apply.
Power sales transactions with durations of one
year or greater are long-term. Transactions
with shorter durations are short-term.
See increment name definitions below.
Terms of the particular sale set for up to 6 consecutive hours (≤ 6 consecutive hours) Includes LMP based sales in ISO/RTO markets.
Terms of the particular sale set for more than 6
and up to 60 consecutive hours (>6 and ≤ 60
consecutive hours). Includes sales over a
peak or off-peak block during a single day.
Terms of the particular sale set for over 60
consecutive hours and up to 168 consecutive hours (>60 and ≤ 168 consecutive
hours). Includes sales for a full week and
sales for peak and off-peak blocks over a
particular week.
Terms of the particular sale set for set for more
than 168 consecutive hours up to, but not including, one year (>168 consecutive hours
and < 1 year). Includes sales for full month
or multi-week sales during a given month.
Terms of the particular sale set for one year or
more (≥ 1 year). Includes all long-term contracts with defined pricing terms (fixed-price,
formula, or index).
To be used only when other available increment names do not apply.
See definitions for increment peaking below.
The product described was sold during Peak
and Off-Peak hours.
The product described was sold only during
those hours designated as off-peak in the
NERC region of the point of delivery.
The product described was sold only during
those hours designated as on-peak in the
NERC region of the point of delivery.
To be used only when the other available increment peaking names do not apply.
Description of product being offered.
The quantity of the product in this transaction.
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30NOR1
71306
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
EQR DATA DICTIONARY—Continued
Field No.
Field
Required
65 .....
Price .............................
✓ ..................................
Number with up to 6
decimals.
65 .......
66 .....
Rate Units ....................
✓ ..................................
66 .......
67 .....
Standardized Quantity
✓ ..................................
See Rate Units Table,
Appendix F.
Number with up to 4
decimals.
67 .......
68 .....
Standardized Price ......
✓ ..................................
Number with up to 6
decimals.
68 .......
69 .....
✓ ..................................
69 .......
70 .....
Total Transmission
Charge.
Total Transaction
Charge.
Number with up to 2
decimals.
Number with up to 2
decimals.
Old
64 .......
Value
Definition
New
✓ ..................................
Actual price charged for the product per unit.
The price reported cannot be averaged or
otherwise aggregated.
Measure appropriate to the price of the product
sold.
For product names energy, capacity, and
booked out power only. Specify the quantity
in MWh if the product is energy or booked
out power and specify the quantity in MW if
the product is capacity.
For product names energy, capacity, and
booked out power only. Specify the price in
$/MWh if the product is energy or booked
out power and specify the price in $/MWmonth if the product is capacity.
Payments received for transmission services
when explicitly identified.
Transaction Quantity (Field 64) times Price
(Field 65) plus Total Transmission Charge
(Field 69).
Index Reporting Data
70 .......
71 .....
Filer Unique Identifier ..
✓ ..................................
FS# (where ‘‘#’’ is an
integer).
71 .......
72 .....
Seller Company Name
✓ ..................................
Unrestricted text (100
characters).
72 .......
73 .....
73 .......
74 .....
Index Price Pub✓ ..................................
lisher(s) To Which
Sales Transactions
Have Been Reported.
Transactions Reported
✓ ..................................
If ‘‘Yes’’ is selected for
Field 13, see Index
Price Publisher, Appendix G.
Unrestricted text (100
characters).
The ‘‘FS’’ seller number from the ID Data table
corresponding to the index reporting company.
The name of the company that is authorized to
make sales as indicated in the company’s
FERC tariff(s). This name must match the
name provided as a Seller’s ‘‘Company
Name’’ in Field Number 2 of the ID Data
(Seller Data).
The index price publisher(s) to which sales
transactions have been reported.
Description of the types of transactions reported to the index publisher identified in this
record.
e-Tag Data
75 .....
e-Tag ID .......................
If an e-Tag ID was
used to schedule the
EQR transaction.
Unrestricted text (30
Characters).
75 .......
76 .....
e-Tag Begin Date ........
If an e-Tag ID was
used to schedule the
EQR transaction.
YYYYMMDD (csv import); MMDDYYYY
(manual entry).
76 .......
77 .....
e-Tag End Date ...........
If an e-Tag ID was
used to schedule the
EQR transaction.
YYYYMMDD (csv import); MMDDYYYY
(manual entry).
77 .......
wreier-aviles on DSK5TPTVN1PROD with
74 .......
78 .....
Transaction Unique
Identifier.
If an e-Tag ID was
used to schedule the
EQR transaction.
Unrestricted text (24
Characters).
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The e-Tag ID contains: The Source Balancing
Authority where the generation is located;
The Purchasing-Selling Balancing Authority
Entity Code; the e-Tag Code; and the Sink
Balancing Authority.
The first date the transaction is scheduled
using the e-Tag ID reported in Field Number
75. Begin Date must not be before the
Transaction Begin Date specified in Field
Number 51 and must be reported in the
same time zone specified in Field Number
56.
The last date the transaction is scheduled
using the e-Tag ID reported in Field Number
75. End Date must not be after the Transaction End Date specified in Field Number
52 and must be reported in the same time
zone specified in Field Number 56.
Unique reference number assigned by the seller for each transaction that must be the
same as reported in Field Number 50.
E:\FR\FM\30NOR1.SGM
30NOR1
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
71307
EQR DATA DICTIONARY
[Appendix A. Product Names]
Contract
product
Transaction
product
Definition
BLACK START SERVICE .....
✓
✓
BOOKED OUT POWER ........
........................
✓
CAPACITY .............................
CUSTOMER CHARGE ..........
✓
✓
✓
✓
DIRECT ASSIGNMENT FACILITIES CHARGE.
EMERGENCY ENERGY ........
✓
........................
✓
........................
ENERGY ................................
ENERGY IMBALANCE ..........
✓
✓
✓
✓
EXCHANGE ...........................
✓
✓
FUEL CHARGE .....................
GENERATOR IMBALANCE ..
✓
✓
✓
✓
GRANDFATHERED BUNDLED.
INTERCONNECTION
AGREEMENT.
✓
✓
✓
........................
MEMBERSHIP AGREEMENT
MUST RUN AGREEMENT ....
NEGOTIATED–RATE
TRANSMISSION.
NETWORK .............................
NETWORK OPERATING
AGREEMENT.
✓
✓
✓
........................
........................
✓
✓
✓
........................
........................
OTHER ...................................
POINT–TO–POINT AGREEMENT.
REACTIVE SUPPLY & VOLTAGE CONTROL.
REAL POWER TRANSMISSION LOSS.
REASSIGNMENT AGREEMENT.
REGULATION & FREQUENCY RESPONSE.
wreier-aviles on DSK5TPTVN1PROD with
Product name
✓
✓
✓
........................
✓
✓
✓
✓
✓
........................
Service available after a system-wide blackout where a generator participates
in system restoration activities without the availability of an outside electric
supply (Ancillary Service).
Energy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction
only).
A quantity of demand that is charged on a $/KW or $/MW basis.
Fixed contractual charges assessed on a per customer basis that could include billing service.
Charges for facilities or portions of facilities that are constructed or used for
the sole use/benefit of a particular customer.
Contractual provisions to supply energy or capacity to another entity during
critical situations.
A quantity of electricity that is sold or transmitted over a period of time.
Service provided when a difference occurs between the scheduled and the
actual delivery of energy to a load obligation (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.
Transaction whereby the receiver accepts delivery of energy for a supplier’s
account and returns energy at times, rates, and in amounts as mutually
agreed if the receiver is not an RTO/ISO.
Charge based on the cost or amount of fuel used for generation.
Service provided when a difference occurs between the output of a generator
located in the Transmission Provider’s Control Area and a delivery schedule from that generator to (1) another Control Area or (2) a load within the
Transmission Provider’s Control Area over a single hour (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.
Services provided for bundled transmission, ancillary services and energy
under contracts effective prior to Order No. 888’s OATTs.
Contract that provides the terms and conditions for a generator, distribution
system owner, transmission owner, transmission provider, or transmission
system to physically connect to a transmission system or distribution system.
Agreement to participate and be subject to rules of a system operator.
An agreement that requires a unit to run.
Transmission performed under a negotiated rate contract (applies only to
merchant transmission companies).
Transmission service under contract providing network service.
An executed agreement that contains the terms and conditions under which a
network customer operates its facilities and the technical and operational
matters associated with the implementation of network integration transmission service.
Product name not otherwise included.
Transmission service under contract between specified Points of Receipt and
Delivery.
Production or absorption of reactive power to maintain voltage levels on
transmission systems (Ancillary Service).
The loss of energy, resulting from transporting power over a transmission system.
Transmission capacity reassignment agreement.
✓
✓
REQUIREMENTS SERVICE
✓
✓
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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.
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.)
Fmt 4700
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E:\FR\FM\30NOR1.SGM
30NOR1
71308
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
EQR DATA DICTIONARY—Continued
[Appendix A. Product Names]
Contract
product
Transaction
product
Definition
SCHEDULE SYSTEM CONTROL & DISPATCH.
✓
✓
SPINNING RESERVE ...........
✓
✓
SUPPLEMENTAL RESERVE
✓
✓
SYSTEM OPERATING
AGREEMENTS.
✓
........................
TOLLING ENERGY ...............
✓
✓
TRANSMISSION OWNERS
AGREEMENT.
✓
........................
UPLIFT ...................................
✓
✓
Scheduling, confirming and implementing an interchange schedule with other
Balancing Authorities, including intermediary Balancing Authorities providing
transmission service, and ensuring operational security during the interchange transaction (Ancillary Service).
Unloaded synchronized generating capacity that is immediately responsive to
system frequency and that is capable of being loaded in a short time period
or non-generation resources capable of providing this service (Ancillary
Service). 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.
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 thirdparty providers (i.e., non-transmission function) are reported.
An executed agreement that contains the terms and conditions under which a
system or network customer shall operate its facilities and the technical and
operational matters associated with the implementation of network.
Energy sold from a plant whereby the buyer provides fuel to a generator (seller) and receives power in return for pre-established fees.
The agreement that establishes the terms and conditions under which a
transmission owner transfers operational control over designated transmission facilities.
A make-whole payment by an RTO/ISO to a utility.
Product name
EQR DATA DICTIONARY
[Appendix B. Balancing Authority]
wreier-aviles on DSK5TPTVN1PROD with
Balancing authority
Abbreviation
AESC, LLC—Wheatland CIN ...............................................................................................................................
Alabama Electric Cooperative, Inc. ......................................................................................................................
Alberta Electric System Operator .........................................................................................................................
Alliant Energy Corporate Services, LLC—East ....................................................................................................
Alliant Energy Corporate Services, LLC—West ...................................................................................................
Ameren Transmission. Illinois ...............................................................................................................................
Ameren Transmission. Missouri ...........................................................................................................................
American Transmission Systems, Inc. .................................................................................................................
Aquila Networks—Kansas ....................................................................................................................................
Aquila Networks—Missouri Public Service ...........................................................................................................
Aquila Networks—West Plains Dispatch ..............................................................................................................
Arizona Public Service Company .........................................................................................................................
Associated Electric Cooperative, Inc. ...................................................................................................................
Avista Corp. ..........................................................................................................................................................
Batesville Balancing Authority ..............................................................................................................................
BC Hydro T & D—Grid Operations ......................................................................................................................
Big Rivers Electric Corp. ......................................................................................................................................
Board of Public Utilities ........................................................................................................................................
Bonneville Power Administration Transmission ...................................................................................................
British Columbia Transmission Corporation .........................................................................................................
California Independent System Operator .............................................................................................................
Carolina Power & Light Company—CPLW ..........................................................................................................
Carolina Power and Light Company—East ..........................................................................................................
Central and Southwest .........................................................................................................................................
Chelan County PUD .............................................................................................................................................
Cinergy Corporation ..............................................................................................................................................
City of Homestead ................................................................................................................................................
City of Independence P&L Dept. ..........................................................................................................................
City of Tallahassee ...............................................................................................................................................
City Water Light & Power .....................................................................................................................................
City Utilities of Springfield .....................................................................................................................................
Cleco Power LLC ..................................................................................................................................................
Columbia Water & Light .......................................................................................................................................
Comision Federal de Electricidad .........................................................................................................................
Comision Federal de Electricidad .........................................................................................................................
Constellation Energy Control and Dispatch .........................................................................................................
Constellation Energy Control and Dispatch—Arkansas .......................................................................................
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E:\FR\FM\30NOR1.SGM
AEWC
AEC
AESO
ALTE
ALTW
AMIL
AMMO
FE
WPEK
MPS
WPEC
AZPS
AECI
AVA
BBA
BCHA
BREC
KACY
BPAT
BCTC
CISO
CPLW
CPLE
CSWS
CHPD
CIN
HST
INDN
TAL
CWLP
SPRM
CLEC
CWLD
CFE
CFEN
GRIF
PUPP
30NOR1
Outside US*
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
✓
........................
........................
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
71309
EQR DATA DICTIONARY—Continued
[Appendix B. Balancing Authority]
wreier-aviles on DSK5TPTVN1PROD with
Balancing authority
Abbreviation
Constellation Energy Control and Dispatch—City of Benton, AR ........................................................................
Constellation Energy Control and Dispatch—City of Ruston, LA ........................................................................
Constellation Energy Control and Dispatch—Conway, Arkansas ........................................................................
Constellation Energy Control and Dispatch—Gila River ......................................................................................
Constellation Energy Control and Dispatch—Glacier Wind Energy ....................................................................
Constellation Energy Control and Dispatch—Harquehala ...................................................................................
Constellation Energy Control and Dispatch—North Little Rock, AK ....................................................................
Constellation Energy Control and Dispatch—Osceola Municipal Light ...............................................................
Constellation Energy Control and Dispatch—Plum Point ....................................................................................
Constellation Energy Control and Dispatch—Red Mesa .....................................................................................
Constellation Energy Control and Dispatch—West Memphis, Arkansas .............................................................
Dairyland Power Cooperative ...............................................................................................................................
DECA, LLC—Arlington Valley ..............................................................................................................................
Duke Energy Corporation .....................................................................................................................................
East Kentucky Power Cooperative, Inc. ...............................................................................................................
El Paso Electric ....................................................................................................................................................
Electric Energy, Inc. ..............................................................................................................................................
Empire District Electric Co., The ..........................................................................................................................
Entergy ..................................................................................................................................................................
ERCOT ISO ..........................................................................................................................................................
Florida Municipal Power Pool ...............................................................................................................................
Florida Power & Light ...........................................................................................................................................
Florida Power Corporation ....................................................................................................................................
Gainesville Regional Utilities ................................................................................................................................
Grand River Dam Authority ..................................................................................................................................
Grant County PUD No. 2 ......................................................................................................................................
Great River Energy ...............................................................................................................................................
Great River Energy ...............................................................................................................................................
Great River Energy ...............................................................................................................................................
Great River Energy ...............................................................................................................................................
GridAmerica ..........................................................................................................................................................
Hoosier Energy .....................................................................................................................................................
Hydro-Quebec, TransEnergie ...............................................................................................................................
Idaho Power Company .........................................................................................................................................
Imperial Irrigation District ......................................................................................................................................
Indianapolis Power & Light Company ..................................................................................................................
ISO New England Inc. ..........................................................................................................................................
JEA .......................................................................................................................................................................
Kansas City Power & Light, Co ............................................................................................................................
Lafayette Utilities System .....................................................................................................................................
LG&E Energy Transmission Services ..................................................................................................................
Lincoln Electric System ........................................................................................................................................
Los Angeles Department of Water and Power ....................................................................................................
Louisiana Energy & Power Authority ....................................................................................................................
Louisiana Generating, LLC ...................................................................................................................................
Louisiana Generating, LLC—City of Conway .......................................................................................................
Louisiana Generating, LLC—City of West Memphis ............................................................................................
Louisiana Generating, LLC—North Little Rock ....................................................................................................
Madison Gas and Electric Company ....................................................................................................................
Manitoba Hydro Electric Board, Transmission Services ......................................................................................
Michigan Electric Coordinated System .................................................................................................................
Michigan Electric Coordinated System—CONS ...................................................................................................
Michigan Electric Coordinated System—DECO ...................................................................................................
MidAmerican Energy Company ............................................................................................................................
Midwest ISO .........................................................................................................................................................
Minnesota Power, Inc. ..........................................................................................................................................
Montana-Dakota Utilities Co. ................................................................................................................................
Muscatine Power and Water ................................................................................................................................
Nebraska Public Power District ............................................................................................................................
Nevada Power Company ......................................................................................................................................
New Brunswick System Operator .........................................................................................................................
New Horizons Electric Cooperative ......................................................................................................................
New York Independent System Operator ............................................................................................................
Northern Indiana Public Service Company ..........................................................................................................
Northern States Power Company .........................................................................................................................
NorthWestern Energy ...........................................................................................................................................
Ohio Valley Electric Corporation ..........................................................................................................................
Oklahoma Gas and Electric ..................................................................................................................................
Ontario—Independent Electricity System Operator .............................................................................................
OPPDCA/TP .........................................................................................................................................................
Otter Tail Power Company ...................................................................................................................................
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E:\FR\FM\30NOR1.SGM
BUBA
DERS
CNWY
GRMA
GWA
HGMA
DENL
OMLP
PLUM
REDM
WMUC
DPC
DEAA
DUK
EKPC
EPE
EEI
EDE
EES
ERCO
FMPP
FPL
FPC
GVL
GRDA
GCPD
GRE
GREC
GREN
GRES
GA
HE
HQT
IPCO
IID
IPL
ISNE
JEA
KCPL
LAFA
LGEE
LES
LDWP
LEPA
LAGN
CWAY
WMU
NLR
MGE
MHEB
MECS
CONS
DECO
MEC
MISO
MP
MDU
MPW
NPPD
NEVP
NBSO
NHC1
NYIS
NIPS
NSP
NWMT
OVEC
OKGE
ONT
OPPD
OTP
30NOR1
Outside US*
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
71310
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
EQR DATA DICTIONARY—Continued
[Appendix B. Balancing Authority]
Balancing authority
Abbreviation
P.U.D. No. 1 of Douglas County ..........................................................................................................................
PacifiCorp-East .....................................................................................................................................................
PacifiCorp-West ....................................................................................................................................................
PJM Interconnection .............................................................................................................................................
Portland General Electric ......................................................................................................................................
Public Service Company of Colorado ..................................................................................................................
Public Service Company of New Mexico .............................................................................................................
Puget Sound Energy Transmission ......................................................................................................................
Reedy Creek Improvement District ......................................................................................................................
Sacramento Municipal Utility District ....................................................................................................................
Salt River Project ..................................................................................................................................................
Santee Cooper ......................................................................................................................................................
SaskPower Grid Control Centre ...........................................................................................................................
Seattle City Light ..................................................................................................................................................
Seminole Electric Cooperative .............................................................................................................................
Sierra Pacific Power Co.—Transmission .............................................................................................................
South Carolina Electric & Gas Company .............................................................................................................
South Mississippi Electric Power Association ......................................................................................................
South Mississippi Electric Power Association ......................................................................................................
Southeastern Power Administration—Hartwell .....................................................................................................
Southeastern Power Administration—Russell ......................................................................................................
Southeastern Power Administration—Thurmond .................................................................................................
Southern Company Services, Inc. ........................................................................................................................
Southern Illinois Power Cooperative ....................................................................................................................
Southern Indiana Gas & Electric Co. ...................................................................................................................
Southern Minnesota Municipal Power Agency .....................................................................................................
Southwest Power Pool .........................................................................................................................................
Southwestern Power Administration .....................................................................................................................
Southwestern Public Service Company ...............................................................................................................
Sunflower Electric Power Corporation ..................................................................................................................
Tacoma Power ......................................................................................................................................................
Tampa Electric Company .....................................................................................................................................
Tennessee Valley Authority ESO .........................................................................................................................
Trading Hub ..........................................................................................................................................................
TRANSLink Management Company ....................................................................................................................
Tucson Electric Power Company .........................................................................................................................
Turlock Irrigation District .......................................................................................................................................
Upper Peninsula Power Co. .................................................................................................................................
Utilities Commission, City of New Smyrna Beach ...............................................................................................
Westar Energy—MoPEP Cities ............................................................................................................................
Western Area Power Administration—Colorado-Missouri ....................................................................................
Western Area Power Administration—Lower Colorado .......................................................................................
Western Area Power Administration—Upper Great Plains East .........................................................................
Western Area Power Administration—Upper Great Plains West ........................................................................
Western Farmers Electric Cooperative ................................................................................................................
Western Resources dba Westar Energy ..............................................................................................................
Wisconsin Energy Corporation .............................................................................................................................
Wisconsin Public Service Corporation .................................................................................................................
Yadkin, Inc. ...........................................................................................................................................................
DOPD
PACE
PACW
PJM
PGE
PSCO
PNM
PSEI
RC
SMUD
SRP
SC
SPC
SCL
SEC
SPPC
SCEG
SME
SMEE
SEHA
SERU
SETH
SOCO
SIPC
SIGE
SMP
SWPP
SPA
SPS
SECI
TPWR
TEC
TVA
HUB
TLKN
TEPC
TIDC
UPPC
NSB
MOWR
WACM
WALC
WAUE
WAUW
WFEC
WR
WEC
WPS
YAD
Outside US*
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
✓
........................
........................
........................
........................
........................
........................
........................
........................
........................
........................
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........................
........................
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........................
........................
........................
........................
........................
........................
........................
........................
........................
* Balancing authorities outside the United States may only be used in the Contract Data section to identify specified receipt/delivery points in
jurisdictional transmission contracts.
EQR DATA DICTIONARY
[Appendix C. Hub]
HUB
Definition
ADHUB .................................
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the AEP/Dayton Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the
AEPGenHub.
The set of delivery points along the California-Oregon commonly identified as and agreed to by the counterparties
to constitute the COB Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into
the Cinergy balancing authority.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) defined by the Midwest Independent Transmission System
Operator, Inc., as Cinergy Hub (MISO).
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into
the Entergy balancing authority.
AEPGenHub .........................
wreier-aviles on DSK5TPTVN1PROD with
COB ......................................
Cinergy (into) ........................
Cinergy Hub (MISO) ............
Entergy (into) ........................
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Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
71311
EQR DATA DICTIONARY—Continued
[Appendix C. Hub]
HUB
Definition
FE Hub .................................
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) defined by the Midwest Independent Transmission System
Operator, Inc., as FE Hub (MISO).
The set of delivery points at the Four Corners power plant commonly identified as and agreed to by the counterparties to constitute the Four Corners Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) defined by the Midwest Independent Transmission System
Operator, Inc., as Illinois Hub (MISO).
The set of delivery points at or near Hoover Dam commonly identified as and agreed to by the counterparties to
constitute the Mead Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) defined by the Midwest Independent Transmission System
Operator, Inc., as Michigan Hub (MISO).
The set of delivery points along the Columbia River commonly identified as and agreed to by the counterparties
to constitute the Mid-Columbia Hub.
The aggregated Elemental Pricing nodes (‘‘Epnodes’’) defined by the Midwest Independent Transmission System
Operator, Inc., as Minnesota Hub (MISO).
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by ISO New England Inc., as Mass Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the Northern
Illinois Hub.
The set of delivery points along the Nevada-Oregon border commonly identified as and agreed to by the counterparties to constitute the NOB Hub.
The set of delivery points north of Path 15 on the California transmission grid commonly identified as and agreed
to by the counterparties to constitute the NP15 Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into
the Northwestern Energy Montana balancing authority.
The aggregated Locational Marginal Price nodes (‘‘LMP’’) defined by PJM Interconnection, LLC as the PJM East
Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the PJM
South Hub.
The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the PJM
Western Hub.
The switch yard at the Palo Verde nuclear power station west of Phoenix in Arizona. Palo Verde Hub includes
the Hassayampa switchyard 2 miles south of Palo Verde.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into
the Southern Company balancing authority.
The set of delivery points south of Path 15 on the California transmission grid commonly identified as and agreed
to by the counterparties to constitute the SP15 Hub.
The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into
the Tennessee Valley Authority balancing authority.
The set of delivery points associated with Path 26 on the California transmission grid commonly identified as and
agreed to by the counterparties to constitute the ZP26 Hub.
Four Corners ........................
Illinois Hub (MISO) ...............
Mead ....................................
Michigan Hub (MISO) ..........
Mid-Columbia (Mid-C) ..........
Minnesota Hub (MISO) ........
NEPOOL (Mass Hub) ..........
NIHUB ..................................
NOB ......................................
NP15 ....................................
NWMT ..................................
PJM East Hub ......................
PJM South Hub ....................
PJM West Hub .....................
Palo Verde ...........................
SOCO (into) .........................
SP15 .....................................
TVA (into) .............................
ZP26 .....................................
EQR DATA DICTIONARY
EQR DATA DICTIONARY
EQR DATA DICTIONARY
[Appendix D. Time Zone]
[Appendix E. Units]
[Appendix F. Rate Units]
wreier-aviles on DSK5TPTVN1PROD with
Time zone
AD
AP
AS
CD
CP
CS
ED
EP
ES
MD
MP
MS
NA
PD
PP
PS
UT
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
...............
VerDate Mar<15>2010
Definition
Atlantic Daylight.
Atlantic Prevailing.
Atlantic Standard.
Central Daylight.
Central Prevailing.
Central Standard.
Eastern Daylight.
Eastern Prevailing.
Eastern Standard.
Mountain Daylight.
Mountain Prevailing.
Mountain Standard.
Not Applicable.
Pacific Daylight.
Pacific Prevailing.
Pacific Standard.
Universal Time.
14:04 Nov 29, 2012
Jkt 229001
Units
KV ...............
KVA .............
KVR .............
KW ..............
KWH ............
KW–DAY .....
KW–MO .......
KW–WK .......
KW–YR .......
MVAR–YR ...
MW ..............
MWH ...........
MW–DAY ....
MW–MO ......
MW–WK ......
MW–YR .......
RKVA ..........
FLAT RATE
PO 00000
Frm 00025
Definition
Kilovolt.
Kilovolt Amperes.
Kilovar.
Kilowatt.
Kilowatt Hour.
Kilowatt Day.
Kilowatt Month.
Kilowatt Week.
Kilowatt Year.
Megavar Year.
Megawatt.
Megawatt Hour.
Megawatt Day.
Megawatt Month.
Megawatt Week.
Megawatt Year.
Reactive Kilovolt Amperes.
Flat Rate.
Fmt 4700
Sfmt 4700
Rate units
Definition
$/KV ............
$/KVA ..........
$/KVR ..........
$/KW ...........
$/KWH .........
$/KW–DAY ..
$/KW–MO ....
$/KW–WK ....
$/KW–YR ....
$/MW ...........
$/MWH ........
$/MW–DAY
$/MW–MO ...
$/MW–WK ...
$/MW–YR ....
$/MVAR–YR
$/RKVA .......
dollars per kilovolt.
dollars per kilovolt amperes.
dollars per kilovar.
dollars per kilowatt.
dollars per kilowatt hour.
dollars per kilowatt day.
dollars per kilowatt month.
dollars per kilowatt week.
dollars per kilowatt year.
dollars per megawatt.
dollars per megawatt hour.
dollars per megawatt day.
dollars per megawatt month.
dollars per megawatt week.
dollars per megawatt year.
dollars per megavar year.
dollars per reactive kilovar
amperes.
cents.
cents per kilovolt amperes.
cents per kilowatt hour.
rate not specified in any other
units.
CENTS ........
CENTS/KVR
CENTS/KWH
FLAT RATE
E:\FR\FM\30NOR1.SGM
30NOR1
71312
Federal Register / Vol. 77, No. 231 / Friday, November 30, 2012 / Rules and Regulations
You may submit either
electronic or written objections and
requests for a hearing identified by
Docket No. FDA–1999–F–4617, by any
of the following methods:
ADDRESSES:
EQR DATA DICTIONARY
[Appendix G. Index Price Publisher]
Index price
publisher abbreviation
AM ...............
EIG ..............
IP .................
P ..................
B ..................
DJ ................
Pdx ..............
SNL .............
Index price publisher
Electronic Submissions
Argus Media.
Energy Intelligence Group,
Inc.
Intelligence Press.
Platts.
Bloomberg.
Dow Jones.
Powerdex.
SNL Energy.
Submit electronic objections in the
following way:
• Federal eRulemaking Portal: https://
www.regulations.gov. Follow the
instructions for submitting comments.
Written Submissions
EQR DATA DICTIONARY
[Appendix H. Exchange/Broker Services]
Exchange/
brokerage
service
BROKER .....
ICE ..............
NYMEX .......
Definition
A broker was used to consummate or effectuate the transaction.
Intercontinental Exchange.
New York Mercantile Exchange.
[FR Doc. 2012–28230 Filed 11–29–12; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF HEALTH AND
HUMAN SERVICES
Food and Drug Administration
21 CFR Part 179
[Docket No. FDA–1999–F–4617 (Formerly
Docket No. 1999F–5321)]
Irradiation in the Production,
Processing and Handling of Food
AGENCY:
Food and Drug Administration,
HHS.
ACTION:
FOR FURTHER INFORMATION CONTACT:
Final rule.
The Food and Drug
Administration (FDA) is amending the
food additive regulations to provide for
the safe use of a 4.5 kilogray (kGy)
maximum absorbed dose of ionizing
radiation to treat unrefrigerated (as well
as refrigerated) uncooked meat, meat
byproducts, and certain meat food
products to reduce levels of foodborne
pathogens and extend shelf life. This
action is in response to a petition filed
by the U.S. Department of Agriculture,
Food Safety and Inspection Service
(USDA/FSIS).
DATES: This rule is effective November
30, 2012. Submit either electronic or
written objections and requests for a
hearing by December 31, 2012. See
section VIII of this document for
information on the filing of objections.
SUMMARY:
wreier-aviles on DSK5TPTVN1PROD with
Submit written objections in the
following ways:
• Fax: 301–827–6870.
• Mail/Hand Delivery/Courier (For
paper or CD–ROM submissions):
Division of Dockets Management (HFA–
305), Food and Drug Administration,
5630 Fishers Lane, rm. 1061, Rockville,
MD 20852.
Instructions: All submissions received
must include the Agency name and
Docket No. FDA–1999–F–4617 for this
rulemaking. All objections received will
be posted without change to https://
www.regulations.gov, including any
personal information provided. For
detailed instructions on submitting
objections, see the ‘‘Objections’’ heading
of the SUPPLEMENTARY INFORMATION
section of this document.
Docket: For access to the docket to
read background documents or
objections received, go to https://
www.regulations.gov and insert the
docket number, found in brackets in the
heading of this document, into the
‘‘Search’’ box and follow the prompts
and/or go to the Division of Dockets
Management, 5630 Fishers Lane, rm.
1061, Rockville, MD 20852.
VerDate Mar<15>2010
14:04 Nov 29, 2012
Jkt 229001
Lane A. Highbarger, Center for Food
Safety and Applied Nutrition (HFS–
255), Food and Drug Administration,
5100 Paint Branch Pkwy., College Park,
MD 20740, 240–402–1204.
SUPPLEMENTARY INFORMATION:
Table of Contents
I. Background
II. Safety Evaluation
A. Radiation Chemistry
B. Toxicological Considerations
C. Nutritional Considerations
D. Microbiological Considerations
III. Labeling
IV. Comments
V. Conclusions
VI. Paperwork Reduction Act of 1995
VII. Environmental Impact
VIII. Objections
IX. Section 301(ll) of the Federal Food, Drug,
and Cosmetic Act
X. References
PO 00000
Frm 00026
Fmt 4700
Sfmt 4700
I. Background
In a notice published in the Federal
Register of December 22, 1999 (64 FR
71792), FDA announced that a food
additive petition (FAP 9M4695) had
been filed by the USDA/FSIS, 300 12th
St. SW., rm. 112, Washington, DC 20250
(currently, Food Safety and Inspection
Service, Stop Code 3782, Patriots Plaza
III, Cubicle 8–163A, 1400 Independence
Ave. SW., Washington, DC 20250–
3700). The petition proposed that the
food additive regulations in part 179,
Irradiation in the Production, Processing
and Handling of Food (21 CFR part 179),
be amended to provide for the safe use
of a 4.5 kGy maximum dose of ionizing
radiation to treat unrefrigerated (as well
as refrigerated 1) uncooked meat, meat
byproducts,2 and certain meat food
products to reduce levels of foodborne
pathogens and extend shelf-life.
FDA’s current regulation under
§ 179.26(b)(8) permits the irradiation of
refrigerated or frozen, uncooked
products that are meat within the
meaning of 9 CFR 301.2(rr), meat
byproducts within the meaning of 9 CFR
301.2(tt), or meat food products within
the meaning of 9 CFR 301.2(uu), with or
without nonfluid seasoning, that are
otherwise composed solely of intact or
ground meat, meat byproducts, or both
meat and meat byproducts. The foods
covered under § 179.26(b)(8) are subject
to the Federal Meat Inspection Act (21
U.S.C. 601, et seq.), and, as described
previously in this document, are
defined by the USDA/FSIS in Title 9 of
the Code of Federal Regulations. In this
document, the term ‘‘meat’’ will be used
to refer collectively to meat, meat
byproducts, and certain meat food
products applicable to this notice.
II. Safety Evaluation
FDA has previously reviewed the
irradiation of meat and meat byproducts
(62 FR 64107, December 3, 1997), and
concluded that the irradiation of
refrigerated meat and meat byproducts
is safe. The current rulemaking concerns
the irradiation of meat at temperatures
that are above refrigerated temperature.
FDA has previously reviewed and
evaluated the safety of irradiated food
products in a variety of applications.
Discussions of these applications have
been presented in various Federal
Register documents (see, e.g., 62 FR
64107 and 70 FR 48057, August 16,
2005). FDA has also updated its review
1 For the purpose of this final rule, refrigeration
temperature is a maximum of 40 °F (4 °C).
2 The Agency notes that in the filing notice dated
December 22, 1999 (64 FR 71792), the phrase ‘‘meat
products’’ was used while the petitioner used the
phrase ‘‘meat byproducts’’ in their filing request
dated August 19, 1999.
E:\FR\FM\30NOR1.SGM
30NOR1
]]>Agencies
[Federal Register Volume 77, Number 231 (Friday, November 30, 2012)]
[Rules and Regulations]
[Pages 71288-71312]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2012-28230]
=======================================================================
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
18 CFR Part 35
[Docket No. RM12-3-000; Order No. 770]
Revisions to Electric Quarterly Report Filing Process
AGENCY: Federal Energy Regulatory Commission, DOE.
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: The Federal Energy Regulatory Commission (Commission) amends
its regulations to change the process for filing Electric Quarterly
Reports (EQR). Due to technology changes that will render the current
filing process outmoded, ineffective, and unsustainable, the Commission
will discontinue the use of Commission-distributed software to file an
EQR. Instead, the Commission adopts a web-based approach to filing EQRs
that will allow a public or non-public utility to file an EQR directly
through the Commission's Web site, either through a web interface or by
submitting an Extensible Mark-Up Language-formatted file. By adopting a
process with two options for filing EQRs, the Commission seeks to
provide the flexibility needed to accommodate a public or non-public
utility's technical preference. The Commission also requires a public
or non-public utility to identify itself with a company identification
number rather than the existing software-based EQR identifier. The
changes to the process for filing EQRs will apply to EQR filings
beginning with the third quarter 2013 EQR, which will provide data for
July through September 2013.
DATES: Effective date: This rule will become effective April 1, 2013.
FOR FURTHER INFORMATION CONTACT:
Connie Caldwell, Office of Enforcement, Federal Energy Regulatory
Commission, 888 First Street NE., Washington, DC 20426, (202) 502-6489,
Connie.Caldwell@ferc.gov.
[[Page 71289]]
Christina Switzer, Office of General Counsel, Federal Energy Regulatory
Commission, 888 First Street NE., Washington, DC 20426, (202) 502-6379,
Christina.Switzer@ferc.gov.
SUPPLEMENTARY INFORMATION:
Before Commissioners: Jon Wellinghoff, Chairman; Philip D. Moeller,
John R. Norris, Cheryl A. LaFleur, and Tony T. Clark.
Final Rule
(Issued November 15, 2012)
Table of Contents
Paragraph
Nos.
I. Introduction............................................. 1
II. Background.............................................. 3
III. Discussion............................................. 6
A. Need for Changing the Current EQR Filing Process..... 6
1. NOPR Proposal.................................... 6
2. Comments......................................... 7
3. Commission Determination......................... 8
B. Option One--Web Interface............................ 9
1. NOPR Proposal.................................... 9
2. Comments......................................... 10
3. Commission Determination......................... 12
C. Option 2--XML-Formatted File......................... 16
1. NOPR Proposal.................................... 16
2. Comments......................................... 17
3. Commission Determination......................... 18
D. Validation........................................... 19
1. NOPR............................................. 19
2. Comments......................................... 20
3. Commission Determination......................... 24
E. Company Registration System.......................... 30
1. NOPR Proposal.................................... 30
2. Comments......................................... 31
3. Commission Determination......................... 33
F. Implementation and Compliance........................ 37
1. NOPR Proposal.................................... 37
2. Comments......................................... 38
3. Commission Determination......................... 47
IV. Information Collection Statement........................ 53
V. Environmental Analysis................................... 64
VI. Regulatory Flexibility Act.............................. 65
VII. Document Availability.................................. 71
VIII. Effective Date and Congressional Notification......... 74
Appendix A: List of Commenters
Appendix B: EQR Data Dictionary
I. Introduction
1. The Federal Energy Regulatory Commission (Commission) adopts
changes to the method for filing Electric Quarterly Reports (EQR). Due
to technology changes that will render the current filing process
outmoded, ineffective, and unsustainable, the Commission will
discontinue the use of Commission-distributed software (EQR software)
to file an EQR. Instead, the Commission adopts a web-based approach
that will allow a public or non-public utility to file an EQR directly
through the Commission's Web site, either through a web interface or by
submitting an Extensible Mark-Up Language (XML)-formatted \1\ file (XML
option). The Commission also requires a public utility or non-public
utility to identify itself with a company identification number
(Company Identifier) rather than the existing software-based EQR
identifier (Personal Identification Number (PIN)). The changes to the
process for filing EQRs will apply to EQR filings beginning with the
third quarter (Q3) 2013 EQR, which will provide data for July through
September 2013.
---------------------------------------------------------------------------
\1\ XML schemas facilitate the sharing of data across different
information systems, particularly via the Internet, by structuring
the data using tags to identify particular data elements. For
example, each filed EQR will include tags for the relevant
information. The tagged information can be extracted and separately
searched.
---------------------------------------------------------------------------
2. Before turning to the requirements in this Final Rule, it is
important to explain certain terms. In the Notice of Proposed
Rulemaking (NOPR), the Commission often used the term ``filer'' in the
description of the two new filing options.\2\ We find that using the
term ``filer'' created confusion because it was not clear whether the
Commission was talking about a public or non-public utility, its agent,
or a respondent. Thus, in this Final Rule, we use the phrase ``EQR
seller'' to mean companies that are authorized to sell power under Part
35 of the Commission's regulations \3\ as well as non-public utilities
\4\ that are
[[Page 71290]]
required to comply with the EQR filing requirements pursuant to the
Electricity Market Transparency Provisions of Section 220 of the
Federal Power Act, Order No. 768.\5\ We use the phrase ``EQR agent'' to
mean an entity that an EQR seller designates to file on its behalf. An
EQR seller will be able to designate multiple EQR agents.\6\ Even when
an EQR agent files on an EQR seller's behalf, the legal obligation for
complying with the EQR requirements remains with the companies that are
authorized to sell power under Part 35 of the Commission's regulations
and non-public utilities, and any inaccuracies are their
responsibility.
---------------------------------------------------------------------------
\2\ Revisions to Electric Quarterly Report Filing Process,
Notice of Proposed Rulemaking, FERC Stats. & Regs. ] 32,689 (2012)
(NOPR).
\3\ See Revised Public Utility Filing Requirements, Order No.
2001, 67 FR 31044 (May 8, 2002), FERC Stats. & Regs. ] 31,127 at
30,116, reh'g denied, Order No. 2001-A, 100 FERC ] 61,074, reh'g
denied, Order No. 2001-B, 100 FERC ] 61,342, order directing filing,
Order No. 2001-C, 101 FERC ] 61,314 (2002), order directing filing,
Order No. 2001-D, 102 FERC ] 61,334, order refining filing
requirements, Order No. 2001-E, 105 FERC ] 61,352 (2003), order on
clarification, Order No. 2001-F, 106 FERC ] 61,060 (2004), order
revising filing requirements, Order No. 2001-G, 72 FR 56735 (Oct. 4,
2007), 120 FERC ] 61,270, at PP 10-11, order on reh'g and
clarification, Order No. 2001-H, 73 FR 1876 (Jan. 10, 2008), 121
FERC ] 61,289 (2007), order revising filing requirements, Order No.
2001-I, 73 FR 65526 (Nov. 4, 2008), FERC Stats. & Regs. ] 32,282
(2008).
\4\ ``Non-public utility'' refers to a market participant that
is not a public utility under section 201(f) of the FPA. FPA section
201(f) provides: No provision in this Part shall apply to, or be
deemed to include, the United States, a State or any political
subdivision of a State, an electric cooperative that receives
financing under the Rural Electrification Act of 1936 (7 U.S.C. 901
et seq.) or that sells less than 4,000,000 megawatt hours of
electricity per year, or any agency, authority, or instrumentality
of any one or more of the foregoing, or any corporation which is
wholly owned, directly or indirectly, by any one or more of the
foregoing, or any officer, agent, employee of any of the foregoing
acting as such in the course of his official duty, unless such
provision makes specific reference thereto. 16 U.S.C. 824(f).
\5\ 77 FR 61896 (Oct. 11, 2012), FERC Stats. & Regs. ] 31,336
(2012)(Transparency Rule). In that rulemaking, the Commission
extended the EQR filing requirements to non-public utilities above a
de minimis market presence threshold and adopted new filing
requirements for both public and non-public utilities.
\6\ The process for designating an EQR agent is discussed in
detail below. See supra, section III.E.
---------------------------------------------------------------------------
II. Background
3. The purpose of the EQR is to
make available for public inspection, in a convenient form and place
all relevant information relating to public utility rates, terms,
and conditions of service; ensure that information is available in a
standardized, user friendly format; and meet the Commission's
electronic filing option obligation. [Footnote omitted.] These
actions also will allow the public to better participate in and
obtain the full benefits of wholesale electric power markets while
minimizing the reporting burden on public utilities.\7\
---------------------------------------------------------------------------
\7\ Order No. 2001, FERC Stats. & Regs. ] 31,127 at 30,116.
The EQR allows public utilities to fulfill their responsibility
under section 205(c) \8\ of the FPA to have rates on file in a
convenient form and place.\9\ Non-public utilities will file EQRs to
meet the requirements under section 220 of the FPA,\10\ as explained in
the Electricity Market Transparency Provisions of Section 220 of the
Federal Power Act, Order No. 768.\11\
---------------------------------------------------------------------------
\8\ 16 U.S.C. 824d(c).
\9\ Order No. 2001, FERC Stats. & Regs. ] 31,127 at P 31.
\10\ EPAct 2005, Public Law 109-58, 119 Stat. 594 (2005).
\11\ Transparency Rule, FERC Stats. & Regs. ] 31,336. In that
rulemaking, the Commission extended the EQR filing requirements to
non-public utilities above a de minimis market presence threshold
and adopted new filing requirements for both public and non-public
utilities.
---------------------------------------------------------------------------
4. Prior to the issuance of Order No. 2001, the Commission required
all public utilities to file in paper format all short-term and long-
term service agreements for cost-based and market-based power sales as
well as service agreements for generally applicable services (such as
point-to-point transmission service). In Order No. 2001, the Commission
replaced the paper filing requirement with an electronic filing
requirement.\12\
The Commission specified that EQRs should ``be prepared in
conformance with the Commission's software and guidance posted and
available for downloading from the FERC Web site (https://www.ferc.gov).'' \13\ Since the fourth quarter of 2002, the Commission
has posted on its Web site a Commission-developed Visual FoxPro
application for filing EQRs (EQR software) that runs on Microsoft
Windows-based computers.\14\
---------------------------------------------------------------------------
\12\ The Commission has refined and clarified the EQR filing
requirements set forth in Order No. 2001 in response to changes in
the industry and the Commission's rules and regulations. For
example, the Commission has required EQR sellers to report all
transmission capacity reassignments and proposed to revise the EQR
Data Dictionary to add ``Simultaneous Exchange'' to the list of
available product names. See Preventing Undue Discrimination and
Preference in Transmission Service, Order No. 890, 72 FR 12266 (Mar.
15, 2007), FERC Stats. & Regs. ] 31,241, at P 817, order on reh'g,
Order No. 890-A, 73 FR 2984 (Jan. 16, 2008), FERC Stats. & Regs. ]
31,261 (2007), order on reh'g and clarification, Order No. 890-B, 73
FR 39092 (July 8, 2008), 123 FERC ] 61,299 (2008), order on reh'g,
Order No. 890-C, 74 FR 12540 (Mar. 25, 2009),126 FERC ] 61,228
(2009), order on clarification, Order No. 890-D, 74 FR 61511 (Nov.
25, 2009), 129 FERC ] 61,126 (2009); Revised Public Utility Filing
Requirements for Electric Quarterly Reports, Notice of Proposed
Rulemaking, 77 FR 16494 (Mar. 21, 2012), FERC Stats. & Regs. ]
32,687 (2012).
\13\ 18 CFR 35.10b.
\14\ See Notice Providing Detail On Electric Quarterly Reports
Software Availability and Announcing Schedule for Software
Demonstrations, Docket No. RM01-8-000 (Dec. 20, 2002).
---------------------------------------------------------------------------
5. On June 21, 2012, the Commission issued a NOPR in this
proceeding to propose changes to the EQR electronic filing process.\15\
On July 11, 2012, the Commission held a technical conference to present
the two new proposed options for filing EQRs. On July 27, 2012, the
Commission posted on its Web site a draft of the XML schema (draft XML
schema) for the proposed XML option so that interested parties would be
able to view the draft XML schema prior to submitting comments on the
NOPR.\16\ The Commission also posted a ``Frequently Asked Questions''
document on its Web site in response to questions raised at the July 11
technical conference.\17\ The Commission received eight comments in
response to the NOPR.\18\
---------------------------------------------------------------------------
\15\ NOPR, FERC Stats. & Regs. ] 32,689.
\16\ Notice of Availability of Draft XML Schema, Docket No.
RM12-3-000 (July 27, 2012). The draft XML-schema is available on the
Commission's Web site at https://www.ferc.gov/docs-filing/eqr.asp.
\17\ The Frequently Asked Questions document is also available
on the Commission's Web site at https://www.ferc.gov/docs-filing/eqr.asp.
\18\ See Appendix A for a list of commenters and their
abbreviated names used here. We note that Southern California Edison
joins EEI's comments.
---------------------------------------------------------------------------
III. Discussion
A. Need for Changing the Current EQR Filing Process
1. NOPR Proposal
6. In the NOPR, the Commission stated that, pursuant to the
Commission's regulations,\19\ EQR sellers and agents must download EQR
software from the Commission's Web site. The Commission explained that
this software was built with Visual FoxPro development tools and must
be installed on a Windows-based computer. The Commission identified
certain disadvantages with the current filing process, such as the fact
that Microsoft, the vendor of Visual FoxPro, announced in 2007 that it
would no longer sell or issue new versions of Visual FoxPro and would
not provide support for the software after 2015. The Commission also
explained that data limitations make the EQR software outmoded,
ineffective, and unsustainable.\20\ The Commission stated that the
changes proposed in the NOPR support the goals of Executive Order 13579
\21\ because the Commission proposed to modify a filing process that
has become outmoded and ineffective. \22\
---------------------------------------------------------------------------
\19\ 18 CFR 35.10b.
\20\ NOPR, FERC Stats. & Regs. ] 32,689 at P 4.
\21\ Regulation and Independent Regulatory Agencies, Exec. Order
13579, 76 FR 41587 (2011). Through this Executive Order, the
President requested that executive agencies retrospectively analyze
their agency's rules and that those found to be outmoded,
ineffective, insufficient, or excessively burdensome be modified,
streamlined, expanded, or repealed in accordance with the results of
that analysis.
\22\ NOPR, FERC Stats. & Regs. ] 32,689 at P 5.
---------------------------------------------------------------------------
2. Comments
7. Commenters understand the technical limitations of the existing
software and the Commission's decision to discontinue it.\23\ Pacific
Gas and Electric commends the Commission for its ongoing efforts to
enhance the efficiency of the EQR data gathering and reporting
process.\24\
---------------------------------------------------------------------------
\23\ See, e.g., Idaho Power at 2; Pacific Gas and Electric at 1.
\24\ Pacific Gas and Electric at 1.
---------------------------------------------------------------------------
3. Commission Determination
8. We conclude that the proposed changes to the method for filing
EQRs are appropriate. As explained in the NOPR, continuing to rely on
the current EQR software is unsustainable because Microsoft will no
longer sell or issue
[[Page 71291]]
new versions of Visual FoxPro.\25\ Further, the data limitations of the
current software make it untenable for use going forward.\26\ As the
Commission also explained, the move from a software-based approach to a
web-based approach will eliminate the need for EQR sellers and agents
to download software from the Commission's Web site.\27\ In addition, a
web-based approach for EQR filing is device-independent, which
eliminates the need for EQR sellers and agents to use a Windows-based
computer to file an EQR.\28\ We also note that the new filing process
will allow EQR sellers and agents to access and revise EQR data filed
prior to Q3 2013.
---------------------------------------------------------------------------
\25\ NOPR, FERC Stats. & Regs. ] 32,689 at P 4.
\26\ Id.
\27\ Id. P 6.
\28\ Id.
---------------------------------------------------------------------------
B. Option One--Web Interface
1. NOPR Proposal
9. In the NOPR, the Commission proposed to offer a web interface on
the Commission's Web site that allows EQR sellers and agents to
continue to enter data in the comma-delimited text (CSV) format but
without the need to download the EQR software.\29\ The Commission
stated that this option would minimize the changes for EQR sellers and
agents and streamline the filing process by eliminating the need for
EQR sellers and agents to enter or import the data into a software
application.
---------------------------------------------------------------------------
\29\ Id.
---------------------------------------------------------------------------
2. Comments
10. Commenters generally support the web interface option as long
as the transition from the current filing process is not overly
difficult or costly.\30\ Some commenters argue that they cannot fully
comment on the web interface option without a live demonstration.\31\
EEI believes that the web interface will allow (1) companies to upload
complete sets of data from prior EQRs, and then edit the information to
reflect changes in the current quarter, rather than having to start
each new EQR from a blank slate; (2) companies to upload new data in
the same CSV format as the current software; and (3) multiple staff
within each company or outside the company with the company's
permission to fill out and review portions of an EQR, though only one
person can be editing a particular EQR at any one time.\32\
---------------------------------------------------------------------------
\30\ See, e.g., EEI at 4; Energy Services Providers at 3; Idaho
Power at 3.
\31\ See, e.g., Idaho Power at 3; Pacific Gas and Electric at 4-
5.
\32\ EEI at 5.
---------------------------------------------------------------------------
11. EPSA requests that the Commission clarify that the proposed web
interface option will be a long-term alternative to the XML option that
will not be phased out in favor of the latter.\33\
---------------------------------------------------------------------------
\33\ EPSA at 3.
---------------------------------------------------------------------------
3. Commission Determination
12. We adopt the web interface as one of two new EQR filing
options. As explained in the NOPR, this option will minimize the
changes for EQR sellers and agents and streamline the filing process by
eliminating the need for EQR sellers and agents to first enter or
import the data into a software application then send it, via Internet,
to the Commission. We are offering this option to make the transition
from the current EQR software to the web interface minimally
disruptive. We direct Commission staff to continue to be available to
answer questions, conduct technical conferences, and post guidance
documents on the Commission's Web site as needed.
13. We emphasize that, as explained in the NOPR, the web interface
will allow EQR sellers and agents to continue to enter data in much the
same way as they currently do: By entering individual fields by hand
(an option used primarily by EQR sellers that have little data to
report) or by uploading data in CSV format. Also, we note that, except
for minor changes, the data elements of the EQR will remain the
same.\34\
---------------------------------------------------------------------------
\34\ The only proposed changes to the EQR data elements adopted
here relate to the addition of a field for the identification of the
EQR seller and the elimination of the respondent field. See
discussion infra section III.E. For recent changes to the EQR filing
requirements, see Transparency Rule, FERC Stats. & Regs. ] 31,336.
---------------------------------------------------------------------------
14. We also point out that, in designing the web interface,
Commission staff has sought to provide the same, if not better,
functionality than is provided in the current EQR software. For
example, once one quarter has been filed in the web interface, a copy
forward function will allow EQR sellers and agents to copy forward
complete sets of identification and contract data and then edit the
data to reflect changes in the current quarter.\35\ Also, an EQR seller
will be able to designate more than one EQR agent to input data on its
behalf. Finally, the use of a web interface will minimize, if not
eliminate, many common EQR filing problems that are due to (1)
conflicts between the current EQR software and other software on the
EQR seller or agent's computer or (2) issues associated with initiating
and supporting the communication functions of the current EQR software.
---------------------------------------------------------------------------
\35\ To assist in the transition to the web interface option,
the EQR seller or agent can import contract data from the Q2 2013
EQR filing made via the current EQR software into the new web
interface after the file is revised to accommodate any new required
fields. See discussion infra section III.F. However, as under the
current EQR software, the web interface will not permit the EQR
seller or agent to copy transaction data forward because the
transactions must correspond to the EQR's designated calendar
quarter.
---------------------------------------------------------------------------
15. Finally, we intend to support the web interface option until
such time as it is no longer needed.
C. Option 2--XML-Formatted File
1. NOPR Proposal
16. In the NOPR, the Commission proposed a second EQR filing option
that allows EQR sellers and agents to file EQR data via XML-formatted
files.\36\ The Commission identified various advantages to the XML
option. For example, an XML schema allows EQR sellers and agents to
test whether their data is consistent with the filing standards before
uploading it to the Commission, thereby improving their ability to
comply with the EQR filing requirement and increasing confidence that
the Commission receives the intended information.\37\
---------------------------------------------------------------------------
\36\ NOPR, FERC Stats. & Regs. ] 32,689 at P 7.
\37\ Id.
---------------------------------------------------------------------------
2. Comments
17. Pacific Gas and Electric believes that the XML option is a
promising solution.\38\ Pacific Gas and Electric states that the XML
format provides the greatest flexibility for processing large amounts
of data and the greatest opportunity to accurately validate data.
However, Pacific Gas and Electric notes that converting data to XML
format requires a software program, authored in-house or by a vendor,
that can create, submit, and store and manage the EQR report.\39\ Idaho
Power supports this filing option if it is similar to the current
filing method and is not overly burdensome and/or does not require
major changes to Idaho Power's internal systems.\40\ Other commenters
do not object to the XML option if it is voluntary and not the sole
means of submission.\41\ EEI supports allowing companies to switch
between the web interface and XML options from one EQR to another.\42\
---------------------------------------------------------------------------
\38\ Pacific Gas and Electric at 6.
\39\ Id. at 5.
\40\ Idaho Power at 2.
\41\ See, e.g., EEI at 7; Energy Services Providers at 3; EPSA
at 4; Idaho Power at 4-5.
\42\ EEI at 7.
---------------------------------------------------------------------------
3. Commission Determination
18. We adopt the XML option as the second of two new filing
options. This
[[Page 71292]]
option allows EQR sellers and agents to file their EQR data in an XML-
formatted file. While we find that allowing EQR sellers and agents to
use the XML option offers several advantages, as highlighted by Pacific
Gas and Electric, and will facilitate the filing of EQRs, we stress
that using the XML option is voluntary. Alternatively, EQR sellers and
agents can choose to file via the web interface. An EQR seller may use
the web interface to file their EQR for one quarter and use the XML
option to file their EQR in another quarter, but an EQR seller cannot
use both options to file its EQR in the same quarter.
D. Validation
1. NOPR
19. In the NOPR, the Commission explained that an XML schema
includes rules and data checks. This allows EQR sellers and agents to
test the consistency of their data with the Commission's filing
standards, thereby improving the ability to comply with EQR filing
requirements and ensures that the Commission receives the intended
information.\43\ The Commission further noted in the NOPR that these
data checks are not available in a CSV file.
---------------------------------------------------------------------------
\43\ NOPR, FERC Stats. & Regs. ] 32,689 at P 7.
---------------------------------------------------------------------------
2. Comments
20. Energy Compliance Consulting requests that the Commission make
available as soon as possible all of the criteria that the Commission
will use to validate an EQR prior to its acceptance for filing.\44\
Energy Compliance Consulting notes that, contrary to the statement in
the posted FAQ document, the draft XML schema posted on the
Commission's Web site contains data elements that EQR filers are not
currently required to provide.\45\ Energy Compliance Consulting
requests that the Commission explain this discrepancy.\46\
---------------------------------------------------------------------------
\44\ Energy Compliance Consulting at 3.
\45\ Id. at 2-3.
\46\ Id. at 3.
---------------------------------------------------------------------------
21. EPSA argues that any new filing method should meet or exceed
the validation capabilities of the Visual FoxPro-based EQR
software.\47\ EPSA asserts that EQR users have not been presented with
meaningful information on how validation checks will be designed for
either the web interface or the XML filing option.\48\ EEI believes
that the web interface will allow companies to upload, edit, and check
for errors in the data before actually filing the EQR; provide pre-
filing error checks and validations for completeness and compliance
with filing requirements; and provide error messages to allow companies
to correct problems before filing their EQRs.\49\ EEI and Links
Technology Solutions ask that the Commission provide a permanent
testing facility (sandbox), like the eTariff sandbox test site, so that
filers can check the basic construction of their XML files and perform
basic types of data checks.\50\
---------------------------------------------------------------------------
\47\ EPSA at 4-5.
\48\ EPSA at 5.
\49\ EEI at 5.
\50\ See, e.g., EEI at 8; Links Technology Solutions at 2.
---------------------------------------------------------------------------
22. Based on information provided during the technical conference,
Pacific Gas and Electric argues that providing email notification for
any validation errors encountered during upload may cause a significant
delay in correcting errors and providing timely EQRs.\51\ Pacific Gas
and Electric claims that using email messages reduces EQR filers'
ability to be quickly alerted of validation errors, which undercuts the
Commission's effort to create a new system on par with, or better than,
the Visual FoxPro-based EQR software.\52\ Pacific Gas and Electric
suggests the web-based system should (1) include on-screen error
reports that are interactive (with links to the error records) or a
user-friendly form (like a spreadsheet) that allows the EQR filer to
immediately and accurately address validation errors, and (2) allow
batch corrections to the error records.\53\ Pacific Gas & Electric
notes that generally accepted data validation rules, which require the
validation process to stop when a critical error is detected, leave
open the possibility that after receiving an error notification and
remedying a set of errors, an EQR filer could receive further error
messages every time the validation routine stops because a critical
error is detected.\54\ Pacific Gas and Electric is concerned about the
impact of this process on timely EQR filing.\55\
---------------------------------------------------------------------------
\51\ Pacific Gas and Electric at 7.
\52\ Id.
\53\ Id.
\54\ Id.
\55\ Id. at 7-8.
---------------------------------------------------------------------------
23. Pacific Gas and Electric also states that, while it generally
supports the Commission's proposal to alter the EQR user authentication
methodology, it is concerned about who will have access to the
sandbox.\56\ Pacific Gas and Electric asserts that restricting access
to only those people authorized to file on behalf of a client, as
suggested at the technical conference, will reduce the filing entities'
current ability to allow anyone within a given company to download a
copy of the current EQR distributed software, load data, and run
validation checks to test some or all of its filing data.\57\ Thus,
Pacific Gas and Electric requests that the Commission provide
authentication protocols in the new system that address these
concerns.\58\
---------------------------------------------------------------------------
\56\ Id. at 8.
\57\ Id.
\58\ Id.
---------------------------------------------------------------------------
3. Commission Determination
24. We find that the validation process in the web interface and
XML-format options will be similar to or better than the validation
process in the current EQR software. We further find that the
validation processes strike an appropriate balance between the needs
identified by commenters and the Commission's resources. We appreciate
Energy Compliance Consulting's request that all the criteria which will
be used to validate an EQR filing prior to its acceptance be made
available as soon as possible. The validation criteria are currently
under development, and the Commission will make these available to the
public as soon as they are complete. As for the discrepancy between the
posted draft XML schema and FAQ document, we note that the draft XML
schema mistakenly included additional data elements that were not
included in the NOPR.
25. Under both of the new EQR filing options, EQR sellers and
agents will be able to log into their eRegistration accounts, load data
and run the validation check. Once an EQR is submitted, the EQR seller
or agent that submitted the EQR will receive the following three
emails: (1) A receipt email that acknowledges that the EQR has been
received; (2) a validation email that will list any business rule
errors, such as listing a transaction under a contract without entering
the contract in the contract section; and (3) an acceptance/rejection
email stating that the EQR is accepted if all validations are passed or
is rejected if any validations fail. The EQR seller and all of its
designated EQR agents will receive the validation email and the
acceptance/rejection email. The validation email will provide a list of
the errors that are contained in submitted data. The system will review
the entire submission prior to creating and sending the validation
report. Due to the number of potential occurrences, the report may not
list all instances of the error, but the EQR seller or agent will be
alerted that that type of error has occurred. Once the EQR seller or
agent has found and corrected all errors in the submission, the EQR
data will be accepted for filing.
26. In addition, both filing options will include a ``Test Only''
option so
[[Page 71293]]
that EQR sellers and agents can submit their filing for data validation
prior to final submission. With respect to the web interface option, we
also have taken steps to address EPSA's request for in-time validation
checks by including some validation checks that will appear on-screen
as the EQR seller or agent inputs the data. These validation checks are
the same as or similar to the validation checks that appear when an EQR
seller or agent uses the current EQR software. For example, an on-
screen error message will appear if a field is left empty that must be
filled, or if an alphabetical character is entered in a numeric field.
After the EQR seller or agent submits its filing, it will receive a
validation email that will provide business logic and data format
errors and line numbers within the body of the email.
27. Pacific Gas and Electric expressed concern that the issuance of
validation emails after the occurrence of each critical error may slow
the filing process. We are not able to avoid the additional time that
the detection of multiple critical errors will add to the filing
process. Validating for business logic errors after a filing is
submitted will allow the Commission to maintain the system during high
volumes of filings. However, we note that EQR sellers and agents will
have the option to run a data validation check prior to submitting the
EQR to the Commission using the ``Test Only'' feature, which should
help alleviate Pacific Gas and Electric's concerns. Moreover, the
Commission expects that the new EQR filing process will be able to
process revised EQR data more quickly and efficiently because it will
have the ability to process only revised data, rather than needing to
process the entire data set to overwrite the previously submitted data,
as currently is the case. By decreasing the amount of processing
capability needed for data updates, the Commission will increase the
available computer capacity for processing the simultaneous filing of
EQRs, resulting in quicker processing of both EQRs and revised EQRs. We
also encourage EQR sellers and agents to submit EQRs early in the
filing period, which starts on the first day after the end of the
quarter providing an entire month to validate the data.
28. With respect to the XML option, we do not find an eTariff type
sandbox is necessary because the ability to test an EQR filing is
integrated into the new system. Specifically, XML files can be imported
into the Web interface, where the EQR seller or agent can select the
``Test Only'' option to receive the validation email for that EQR
filing. Additionally, EQR sellers and agents may use one of many XML
parser programs available free on-line to check whether their XML file
is consistent with the EQR XML schema. The parser will check for data
formatting errors, which an EQR seller or agent can then correct. If
there are business logic errors that were undetected by the parser, a
validation email will notify the EQR seller and agent contacts.
29. We decline to adopt Pacific Gas and Electric's request to
include the ability to perform batch corrections to records that
contain errors. The current EQR software does not provide a way to
perform batch corrections; and we are not persuaded to include that
capability in the new filing options. This correction method could
arbitrarily and incorrectly change the contents of an EQR. We note,
however, that EQR sellers and agents who intend to file by uploading
CSV or XML files can develop their own batch correction processes to
respond to validation errors.
E. Company Registration System
1. NOPR Proposal
30. In the NOPR, the Commission proposed to replace the PIN number
identification system with the Company Registration System used for
eTariff filings.\59\ The Commission explained that the PIN system is
part of the EQR software, and as part of the transition away from this
software application, the Commission must provide a new manner to
identify EQR sellers. The Commission stated that, as part of the
development of the eTariff system, the Commission directed each
publicly regulated company to file its tariffs, rate schedules,
jurisdictional contracts, and other jurisdictional agreements with a
Company Identifier. Accordingly, the Commission stated that it does not
anticipate that the use of a Company Identifier in the EQR filing
process will create an undue burden for publicly regulated companies
that file their Commission-jurisdictional tariffs and agreements
because they already have Company Identifiers. The Commission also
stated that it did not anticipate that the use of the Company
Identifier will be unduly burdensome for an EQR filer that does not
have an existing Company Identifier because the registration process on
the Commission's Web site is straightforward and no more difficult than
the current filer identification process. The Commission also noted
that an advantage of using the Company Identifier for EQR filings is
that it will make filer identification consistent with other
filings.\60\
---------------------------------------------------------------------------
\59\ NOPR, FERC Stats. & Regs. ] 32,689 at P 9.
\60\ Id.
---------------------------------------------------------------------------
2. Comments
31. EEI supports the Commission's plan to continue to accommodate a
wide variety of EQR filing arrangements, including (1) filings
submitted on behalf of respondents that are not registered companies
(i.e., entities that do not have Company Identifiers); (2) a single
respondent filing on behalf of multiple sellers; (3) a single seller
submitting multiple EQRs for the same quarter through different
respondents; (4) a seller that consists of multiple registered
companies or an unregistered service company; and (5) law-firm
personnel and others filing as agents for respondents.\61\ However, EEI
states that the Commission may need to provide additional flexibility
as to individuals and entities that can register and obtain a Company
Identifier using the eRegistration system.\62\ EEI asks the Commission
to allow filings by anyone who has the necessary Company Identifier and
password without limiting filings to a pre-approved list of specific
individuals.\63\ EEI urges the Commission to post instructions for
company registration similar to the instructions that the Commission
posted for company registration for eTariff.\64\
---------------------------------------------------------------------------
\61\ EEI at 3.
\62\ Id. at 4. This document is located on the Commission's Web
site at https://www.ferc.gov/docs-filing/company-registration-instruct.pdf, and the current version is dated October 6, 2011.
\63\ Id.
\64\ Id. (citing FERC Secretary of the Commission, eTariff
Instructions for Company Registration (2009), https://www.ferc.gov/docs-filing/company-registration-instruct.pdf (The Commission up-
dated the instructions on October 6, 2011)).
---------------------------------------------------------------------------
32. Based on information provided at the technical conference, EPSA
asks the Commission to reconsider requiring companies to designate in
advance of making a filing who is authorized to make EQR filings.\65\
EPSA states that its members have cautioned that requiring companies to
designate in advance who is permitted to file their EQRs may prove more
unwieldy than anticipated.\66\ EPSA states that its members own
numerous project companies and that the administrative burden
associated with initially designating agents and back-up agents on what
could be over fifty company registrations and changing each of those
delegations in anticipation of staffing changes or in case of
emergencies is unnecessary.\67\ EPSA further states that
[[Page 71294]]
there are already security protections in place to ensure an authorized
person is making filings with the Commission.\68\ Finally, EPSA asserts
that, because Commission staff's approval of modifications to a
company's registration can take up to 24 hours to become effective, a
company's filing may become untimely.\69\ EPSA states that, in the
eTariff context, where delegations are not needed and thus
modifications to company registration are not routine, the modification
of company registrations has delayed filings.\70\
---------------------------------------------------------------------------
\65\ EPSA at 5.
\66\ Id.
\67\ Id.
\68\ Id. at 6.
\69\ Id.
\70\ Id.
---------------------------------------------------------------------------
3. Commission Determination
33. The Commission adopts the requirement for EQR sellers to
identify themselves using a Company Identifier. As explained in the
NOPR, the PIN system is part of the current EQR software. Therefore, as
part of the transition away from the EQR software, the Commission must
provide a new manner to identify EQR sellers. Instead of building a new
identification system for submitting EQRs, we will utilize the company
registration system that was created for eTariff. Using the company
registration system to identify EQR sellers allows the Commission to
make filer identification consistent with other Commission filings and
is familiar to public utilities that use eTariff. Under the new EQR
filing system, all EQR sellers will be identified in EQR filings by
their Company Identifier.\71\
---------------------------------------------------------------------------
\71\ The current PIN system requires an EQR seller to share its
PIN and password with all individuals that it wants to allow to file
on its behalf, and we do not consider this to be a safe practice. We
believe that this creates the potential for unanticipated problems
and that it is not the most secure method of filing.
---------------------------------------------------------------------------
34. To make an EQR filing, the EQR seller will request a Company
Identifier through the Commission's Company Registration System.\72\
The EQR seller will be able to maintain a list of eRegistered EQR
agents whom the EQR seller has authorized to submit EQR filings on its
behalf.\73\ An EQR seller can designate multiple individuals as its
agents. The EQR agent will use its eRegistration account to log onto
FERC Online,\74\ and select from a list of EQR seller(s) that have
designated the individual as EQR agent.
---------------------------------------------------------------------------
\72\ See https://www.ferc.gov/docs-filing/company-reg.asp. Many
EQR sellers have a Company Identifier and do not need to request a
new Company Identifier. If an EQR seller is not sure whether it
already has a Company Identifier, it can check the list of Company
Identifiers on the Commission's Web site at https://www.ferc.gov/industries/electric/gen-info/reg-ent.asp.
\73\ An individual must eRegister before an EQR seller can
designate that person as an EQR agent. See https://www.ferc.gov/docs-filing/eregistration.asp.
\74\ See https://www.ferc.gov/docs-filing/ferconline.asp.
---------------------------------------------------------------------------
35. We understand that requiring EQR sellers to designate agents
that have eRegistered is more burdensome than the current system.
However, after the initial burden of designating EQR agents, we
anticipate that it will be minimally burdensome for an EQR seller to
manage its EQR agent list. For instance, since an EQR seller may
designate an unlimited number of agents, if one agent is unable to file
in a given quarter, another agent will be able to make the filing.
Finally, in response to EPSA's concern, Commission staff will not
review changes that a company makes to the list of EQR agents
associated with its Company Identifier account. These changes will be
instantaneous.\75\
---------------------------------------------------------------------------
\75\ We note that Commission staff does review applications for
a Company Identifier account and that review can take up to several
days.
---------------------------------------------------------------------------
36. We note that the new identification system will provide an
electronic record of the EQR agent(s) that have filed an EQR on behalf
of an EQR seller. Accordingly, we will eliminate the respondent fields
from the EQR data dictionary because it no longer provides useful
information to the Commission or the public. We are aware that some
companies use the respondent field to indicate that a service company
or parent company is filing on behalf of several operating companies or
affiliates that are the EQR sellers. While a parent company or service
company may file EQRs on behalf of EQR sellers, an individual will need
to be eRegistered and designated as an agent of the EQR sellers. The
designated agent may then file an EQR on behalf of the EQR seller. EEI
also suggests that an EQR seller could be a service company. We note
that a service company may be listed as an EQR seller if the service
company is authorized to sell power under Part 35 of the Commission's
regulations, or if a public utility's tariff authorizes the service
company to act on its behalf.\76\
---------------------------------------------------------------------------
\76\ See Order No. 2001-G, 120 FERC ] 61,270 at PP 10-11 (``the
agent may be identified as the Seller if the company's tariff
authorizes the agent to make the sales.'').
---------------------------------------------------------------------------
F. Implementation and Compliance
1. NOPR Proposal
37. In the NOPR, the Commission proposed that implementation of any
changes to the process for filing EQRs will apply to EQR filings
beginning with the Q3 2013 EQR, providing data for July through
September 2013.\77\ The Commission stated that implementing the changes
within that time period should provide EQR sellers with sufficient time
to weigh the two options and file their Q3 2013 EQR in a timely manner.
---------------------------------------------------------------------------
\77\ NOPR, FERC Stats. & Regs. ] 32,689 at P 11.
---------------------------------------------------------------------------
2. Comments
38. Some commenters request that the Commission extend the
compliance date.\78\ For example, EEI requests that the compliance date
be at least one full year after the Commission issues a Final Rule and
the EQR filing web interface is pre-tested, corrected, and available
for general use before withdrawing the current FoxPro-based software
filing option.\79\ EEI states that this time would give companies a
chance to test the new web interface and iron out any problems before
the current FoxPro-based software is no longer an option.\80\
---------------------------------------------------------------------------
\78\ See, e.g., EEI at 8; Links Technology Solutions at 2;
Pacific Gas and Electric at 6.
\79\ EEI at 8.
\80\ EEI at 8.
---------------------------------------------------------------------------
39. As for the XML filing option, commenters argue that it takes at
least 12 months to develop and test software to file in XML and to
train staff on using the software.\81\ Pacific Gas and Electric states
that software vendors cannot design and offer products to customers
until they have a final XML schema document.\82\ Pacific Gas and
Electric asserts that it is only after vendors make their products
available that customers can evaluate and purchase products, and begin
retooling their internal business processes to accommodate the new EQR
requirements.\83\ Thus, Pacific Gas and Electric requests that the
Commission give regulated entities one year from the date a Final Rule
is published in the Federal Register to make the necessary internal
data collection changes and to acquire, install, and test the software
to file new-system EQR submittals.\84\ Similarly, EEI requests that the
Commission provide a full year after it issues a final XML Data
Structure and XML Data Values, holds a technical conference to discuss
the XML filing option, and issues a Final Rule in this proceeding
before withdrawing the current software.\85\
---------------------------------------------------------------------------
\81\ See, e.g., EEI at 8; Pacific Gas and Electric at 6.
\82\ Pacific Gas and Electric at 6.
\83\ Pacific Gas and Electric at 6.
\84\ Pacific Gas and Electric at 6.
\85\ EEI at 8.
---------------------------------------------------------------------------
40. Several commenters assert that the Commission should conclude
any other EQR-related rulemakings before changing the EQR filing
process so that filers do not need to modify their system
[[Page 71295]]
multiple times.\86\ In addition, EEI also states that the Commission
will need to keep the web interface and XML schema up-to-date to
accommodate any future changes to the EQR, providing adequate notice of
such changes and time for EQR filers and software vendors to adopt the
changes.\87\
---------------------------------------------------------------------------
\86\ See, e.g., EEI at 9-10; Energy Compliance Consulting at 2;
EPSA at 6, 9-10.
\87\ EEI at 10.
---------------------------------------------------------------------------
41. EEI and Idaho Power recommend that the Commission allow filers
to file their EQR in the current software and proposed new web
interface during the transition period.\88\ Idaho Power recommends that
the Commission do so for a minimum of two reporting periods after the
proposed implementation date listed in the NOPR.\89\ EEI asserts that
this time would ensure that filers will not be penalized because of
problems with the web interface or XML option.\90\ Idaho Power states
that this grace period will give filers time to transition, train, and
modify existing internal systems.\91\ In the alternative, Idaho Power
recommends and supports thorough testing by a representative sample of
filers prior to the proposed implementation date in the NOPR to
identify and correct system issues.\92\
---------------------------------------------------------------------------
\88\ See, e.g., EEI at 9; Idaho Power at 3-4.
\89\ Idaho Power at 3.
\90\ EEI at 9.
\91\ Idaho Power at 3.
\92\ Id. at 4.
---------------------------------------------------------------------------
42. Several commenters request that the Commission hold a second
technical conference that includes a live demonstration of the new
filing options.\93\ Idaho Power states that Commission staff should
provide a thorough live demonstration of the proposed web interface,
including but not limited to walking through the steps of a complete
start to finish EQR filing.\94\ Energy Compliance Consulting states
that the demonstration should show more completely how filers will
interact with the software and include the submission of very large
files and files with numerous errors so that prospective users will
know how the system will present those errors and what the time will be
compared to the current EQR software.\95\ EEI states that the
demonstration should be available by computers and should accommodate
questions and provide answers in real time, similar to an EQR user
group conference call.\96\ Pacific Gas and Electric requests that the
Commission schedule another technical conference in the near future to
further present system functionalities and capabilities because a Final
Rule in this matter may establish a level of certainty about the
technical functions and behavior of the new system on both the server
and client side of the equation.\97\
---------------------------------------------------------------------------
\93\ See, e.g., EEI at 6; Energy Compliance Consulting at 4;
Idaho Power at 4; Pacific Gas and Electric at 9.
\94\ Idaho Power at 4.
\95\ Energy Compliance Consulting at 4.
\96\ EEI at 7.
\97\ Pacific Gas and Electric at 9.
---------------------------------------------------------------------------
43. EEI asserts that filers and vendors may have questions about
adopting the structure and values for use in filing EQR data in XML
format.\98\ Therefore, EEI encourages the Commission to hold a
conference call/meeting to discuss the XML option only so that the
Commission can answer questions about use of the data structure and
values, correct problems, and help avoid errors in use of the
option.\99\
---------------------------------------------------------------------------
\98\ EEI at 7.
\99\ Id. at 7-8.
---------------------------------------------------------------------------
44. Some commenters recommend that the Commission work with
companies and software vendors to test the proposed new web interface
before it goes public.\100\ EEI states that problems may include
missing functions that the software currently provides, inability to
upload data required in various columns or rows, errors in how the web
interface handles data being uploaded, or unclear filing
instructions.\101\ EEI encourages the Commission to ensure that the new
web interface is fully tested for anomalies and corrected to remove
problems before it is made available for general use.\102\ EEI offers
to ask for volunteers for this effort from among its members.\103\
---------------------------------------------------------------------------
\100\ See, e.g., EEI at 6; Energy Compliance Consulting at 5.
\101\ EEI at 6.
\102\ Id. at 5-6.
\103\ Id. at 6.
---------------------------------------------------------------------------
45. CAISO and Idaho Power state that, based on the technical
conference and FAQ document, it appears as though the copy forward
function will not be available for the initial Q3 2013 EQR filing so
that respondents will be responsible for transferring all data to the
new web interface.\104\ CAISO and Idaho Power assert that requiring
respondents to enter all of the pre-existing data manually rather than
through an automated procedure would be burdensome and strain filers'
time and resources.\105\ Idaho Power requests that the Commission
develop an automated method, or provide detailed instructions on how to
load or transfer the existing data from the FoxPro system into the new
system for the initial web interface filing.\106\ Similarly, CAISO
argues that the Commission should be responsible for populating the
database that underlies the new web interface with the data from the
EQR respondents' Q2 2013 EQR.\107\ CAISO asserts that the Commission
already will possess all of the data submitted by respondents for Q2
2013 EQR, and thus be better situated to perform the necessary data
transfer.\108\ CAISO also asserts that it is concerned that errors may
be introduced into the data if the process of incorporating previously
submitted data is made more complicated than the current copy forward
method.\109\
---------------------------------------------------------------------------
\104\ CAISO at 4; Idaho Power at 4.
\105\ CAISO at 3; Idaho Power at 4.
\106\ Idaho Power at 4.
\107\ CAISO at 3-4.
\108\ Id. at 3.
\109\ Id. at 4-5.
---------------------------------------------------------------------------
46. EEI states that the proposed changes to the regulatory text are
too ambiguous, particularly the reference to ``as otherwise provided to
the public'' because it does not specify where and how the Commission
will provide such guidance.\110\ EEI also suggests that the Commission
publish notices in the Federal Register anytime the Commission posts
generally applicable guidance or similar documents on the Commission's
Web site to ensure that the regulated community has prompt and adequate
notices of the new information.\111\ Thus, EEI recommends that the
Commission modify the proposed regulatory text to read, ``Electric
Quarterly Reports must be prepared in conformance with Commission
guidance being published in the Federal Register.'' \112\
---------------------------------------------------------------------------
\110\ EEI at 11.
\111\ Id. at 11-12.
\112\ Id. at 12.
---------------------------------------------------------------------------
3. Commission Determination
47. We direct EQR sellers to comply with the changes to the process
for filing EQRs beginning with the Q3 2013 EQR, providing data for July
through September 2013. We find that this time period provides EQR
sellers with sufficient time to choose between the two filing options,
transition to the new filing process, and file their Q3 2013 EQR in a
timely manner. We disagree with commenters that argue that EQR sellers
will need up to a year to adapt to the new filing options. As explained
above,\113\ the web interface option will operate similar to the
current software and should not require significant changes to an EQR
seller's existing internal system. An EQR seller that would like to
file using the XML option, but is not prepared to do so by the filing
deadline for Q3 2013 EQR, can file
[[Page 71296]]
through the web interface until it is able to transition to the XML
option.
---------------------------------------------------------------------------
\113\ See discussion supra section III.A.
---------------------------------------------------------------------------
48. Starting with Q3 of 2013, we will no longer be able to accept
EQR filings submitted through the current EQR software. In the
Transparency Rule, the Commission revised the EQR filing requirements,
adding some fields and deleting others.\114\ Due to technical
limitations, the Commission cannot add the new fields to the current
EQR software. Therefore, consistent with the compliance deadline in the
Transparency Rule, EQR sellers must file using the new filing process
beginning with Q3 of 2013.
---------------------------------------------------------------------------
\114\ Transparency Rule, FERC Stats. & Regs. ] 31,336.
---------------------------------------------------------------------------
49. As explained throughout this Final Rule, the Commission will
assist EQR sellers and agents in transitioning to the new filing
process. The Commission directs staff to hold technical conferences to
explain the new filing process as needed. However, the Commission will
not offer a live demonstration of the new EQR filing options because
the technology is still in development and will not be completed until
after the rulemaking process is complete.
50. The Commission cannot pre-populate the new filing Web interface
with Q2 2013 EQR data because the Web interface will include new fields
that will not be present in the Q2 2013 EQR. However, we remind EQR
sellers and agents that the current EQR software includes the ability
to export a CSV file. EQR sellers and agents can export a CSV file from
the EQR software that companies could then use, after revisions have
been made to accommodate new requirements, to import into the new web-
based system.
51. We agree with EEI that the reference to ``as otherwise provided
to the public'' in the proposed regulatory text is ambiguous.
Accordingly, we have removed that phrase from the regulatory text
adopted in this Final Rule, and adopt text that states that ``Electric
Quarterly Reports must be prepared in conformance with the Commission's
guidance posted on the FERC Web site (https://www.ferc.gov).'' We
disagree with EEI that the Commission should publish a notice in the
Federal Register every time the Commission posts new guidance on the
Commission's Web site. The Commission publishes notices when it
proposes changes to existing requirements, but we do not find it
necessary to publish a notice in the Federal Register whenever the
Commission posts, for example, answers to frequently asked questions.
IV. Information Collection Statement
52. The Office of Management and Budget (OMB) requires that OMB
approve certain information collection and data retention requirements
imposed by agency rules.\115\ Therefore, the Commission is submitting
the proposed modifications to its information collection statement to
OMB for review and approval in accordance with section 3507(d) of the
Paperwork Reduction Act of 1995.\116\
---------------------------------------------------------------------------
\115\ 5 CFR 1320.11(b) (2010).
\116\ 44 U.S.C. 3507(d) (2006).
---------------------------------------------------------------------------
53. OMB's regulations require approval of certain information
collection requirements imposed by agency rules. Upon approval of a
collection(s) of information, OMB will assign an OMB control number and
an expiration date. Respondents subject to the filing requirements of a
rule will not be penalized for failing to respond to these collections
of information unless the collections of information display a valid
OMB control number.
54. The Commission is submitting these reporting requirements to
OMB for its review and approval under section 3507(d) of the Paperwork
Reduction Act. Comments were solicited on the Commission's need for
this information; whether the information will have practical utility;
the accuracy of provided burden estimates; ways to enhance the quality,
utility, and clarity of the information to be collected; and any
suggested methods for minimizing the respondent's burden, including the
use of automated information techniques.\117\
---------------------------------------------------------------------------
\117\ NOPR, FERC Stats. & Regs. ] 32,689 at P 13.
---------------------------------------------------------------------------
55. Some commenters question the Commission's burden estimate.\118\
Energy Compliance Consulting states that there is no explanation of why
a utility's membership in a regional transmission organization (RTO)
would affect its filing burden.\119\ Energy Compliance Consulting also
states that it is unclear whether the burden estimate assumes how many,
if any, utilities will move to the new XML format.\120\ Pacific Gas and
Electric asserts that the Commission's burden estimates fall short of
the cost of transitioning to the XML option.\121\
---------------------------------------------------------------------------
\118\ See, e.g., Energy Compliance at 5; Pacific Gas and
Electric at 6.
\119\ Energy Compliance Consulting at 5.
\120\ Energy Compliance Consulting at 5.
\121\ Pacific Gas and Electric at 6.
---------------------------------------------------------------------------
56. We find that a public utility's membership in an RTO or
independent transmission system operator (ISO) should not affect the
burden of complying with the Final Rule. Consequently, for this Final
Rule, we estimate that the one-time burden hours, the recurring burden
hours, and the average annual burden hours will be the same for all EQR
sellers, irrespective of membership in an RTO or ISO. We have broken
out EQR sellers by RTO/ISO membership status simply to be consistent
with the way that the Commission estimated the average burden per
respondent associated with the existing EQR system in a separate filing
submitted to OMB.\122\
---------------------------------------------------------------------------
\122\ See NOPR, Stats. & Regs. ] 32,689 at n.17.
---------------------------------------------------------------------------
57. In the NOPR, the Commission estimated the number of hours
required for public utilities to comply with the minimum requirements
included in the NOPR. While public utilities may opt to use the XML
option, we consider the move to the Web interface to be a less
burdensome option for public utilities because it builds upon the
automated systems that they have developed to enter data into the
current EQR software. Thus, the Commission's burden estimate did not
estimate how many public utilities will voluntarily transition to the
XML option or the number of hours required for a public utility to
transition to the XML option.
58. The Commission's estimates of the average public reporting
burden and cost related to the proposed rule in Docket RM12-3-000 are
as follows:
[[Page 71297]]
Final Rule in RM12-3-000 on Electric Quarterly Report
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Number of Implementing (one-time) burden Recurring operating burden per respondent per Average annual burden per respondent
responses per respondent response \123\ (implementation averaged over years 1-3)
Number of per -------------------------------------------------------------------------------------------------------------------------------
respondents respondent
per year Burden hours Cost ($) Burden hours \124\ Cost ($) Burden hours Cost ($)
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Companies within non-California RTO, 405 4 20 $1,434.50 no change............. no change............. 6.67.................. $478.17.
and large cos. within Cal. RTO.
Medium/small companies within Cal. 20 4 20 $1,434.50 no change............. no change............. 6.67.................. $478.17.
RTO.
Companies not within RTO............ 663 4 20 $1,434.50 no change............. no change............. 6.67.................. $478.17.
Companies with no transactions...... 695 4 20 $1,434.50 no change............. no change............. 6.67.................. $478.17.
Sub-Total--All Public Utilities 1,783 4 35,660 $2,557,713.50 no change............. no change............. 11,892.61............. $852,577.11.
(Existing Filers).
Non Public Utilities (New Filers)... 53 4 .............. .............. no change............. no change............. no change............. no change.
Total--All Utilities............ 1,836 4 35,660 $2,557,713.50 no change............. no change............. 11,892.61............. $852,577.11.
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
59. The total estimated one-time implementation burden and cost
for all respondents is 35,660 hours (1,783 x 20 hours), and
$2,557,713.50 (1,783 x $1,434.50). Averaging this one-time
implementation burden and cost over Years 1-3 yields an annual total
burden of 11,892.61 hours (1,783 x 6.67) and an annual total cost of
$852,577.11 (1,783 x $478.17)
---------------------------------------------------------------------------
\123\ The Commission expects no change or a slight decrease in
the Recurring Operating Burden per Respondent per Response under the
new filing system (when compared to quarterly filings for current
filers under the existing system).
\124\ For the current EQR software and reporting requirements,
the Commission estimates the average burden per respondent per
quarterly filing to be: 32 hours for Companies within non-California
RTO, and large companies within the California RTO; 80 hours for
medium/small Companies within the California RTO; 3 hours for
Companies not within an RTO; and 0.083 hours [5 minutes] for
Companies with no transactions.
---------------------------------------------------------------------------
60. We recognize that there will be an initial implementation
burden for current EQR sellers (filers) associated with reviewing
instructions, revising filing process, obtaining a Company Identifier,
designating an agent(s), and filing EQR data through the new system. We
estimate a burden of 20 hours per existing respondent for this one-
time, initial implementation burden. The Transparency Rule requires
non-public utilities to file EQRs for the first time in Q3 of 2013,
consistent with the implementation date of this Final Rule.\125\ Non-
public utilities will file for the first time using the new filing
options and will not need to transition from the current EQR software.
Therefore, we estimate no change for non-public utilities.
---------------------------------------------------------------------------
\125\ Transparency Rule, FERC Stats. & Regs. ] a P 31,336. The
burden on non-public utilities associated with filing EQRs was
captured in the Transparency Rule. In the Transparency Rule, the
Commission estimated per non-public utility 400 hours for one-time
implementation, and 19 hours for recurring burden for each quarterly
filing. The estimated average annual burden per non-public utility
(with implementation averaged over Years 1-3) was 209.33 hours.
---------------------------------------------------------------------------
61. To help with the implementation of this Final Rule, we will
direct Commission staff to convene a staff-led technical conference for
industry participants to demonstrate the two new options for filing
EQRs. The conference will be available by webcast, which should
minimize travel and other costs associated with participation in the
conference. We will also direct staff to assist in transitioning to the
new process. Commission staff's technical conference and assistance
should minimize the initial implementation burden.
62. For the recurring effort involved in electronically submitting
EQR data on a quarterly basis to the Commission, we anticipate that
there will be no change or a slight burden reduction for current filers
compared to the burden of making quarterly filings under the current
system.
Information Collection Costs: We estimate the cost of compliance
per existing respondent will be $1,434.50, for one-time implementation
of the changes proposed in this Final Rule. We estimate that the
implementation costs will be as follows: \126\
---------------------------------------------------------------------------
\126\ Hourly average wage is an average and was calculated using
Bureau of Labor Statistics (BLS), Occupational Employment Statistics
data for May 2011 (for NAICS 221100--Electric Power Generation,
Transmission and Distribution, at https://bls.gov/oes/current/naics4_221100.htm#00-0000) for the senior accountant, financial
analyst, information technology analyst, and support staff. The
average hourly figure for legal staff is a composite from BLS and
other resources.
---------------------------------------------------------------------------
Legal staff (at $250/hour), for 2 hours, costing $500
Senior accountant (at $51.38/hr.), financial analyst (at
$68.12/hr.), and/or support staff (at $35.99/hr.), averaged at $51.83/
hr., for a total of 2 hours, costing $103.66
Information technology analyst (at $57.24/hour), for 12
hours, costing $686.88
Support staff (at $35.99/hr), for 4 hours, costing
$143.96.
TITLE: FERC-920,\127\ Electric Quarterly Report, OMB Control No.
1902-0255.
---------------------------------------------------------------------------
\127\ The Commission is separating the EQR reporting
requirements from the remaining reporting requirements under FERC-
516 (Electric Rate Schedules and Tariff Filings, OMB Control No.
1902-0096). After implementation of this Final Rule and issuance of
an OMB decision, the EQR burden figures will be removed from FERC-
516.
---------------------------------------------------------------------------
Action: Proposed new EQR filing system and associated additional
reporting requirements.
Respondents: Electric utilities.
Frequency of Responses: Initial implementation and quarterly
filings (beginning Q3 of 2013).
Need For Information: We are implementing changes to the method for
filing EQRs. We are replacing a filing system that requires the use of
Commission software with a system that would allow an EQR seller to
file EQR data directly through the Commission's Web site, either
through a Web interface or by submitting an XML-formatted file. We are
also requiring the EQR seller to identify itself with a Company
Identifier that will be assigned through the Commission's Company
Registration System.
[[Page 71298]]
Internal Review: We have reviewed the changes and determined that
the changes are necessary. These requirements conform to the
Commission's need for efficient information collection, communication,
and management within the energy industry. We have assured ourselves,
by means of internal review, that there is specific, objective support
for the burden estimates associated with the information collection
requirements.
63. Interested persons may obtain information on the reporting
requirements by contacting: Federal Energy Regulatory Commission, 888
First Street NE., Washington, DC 20426 [Attention: Ellen Brown, Office
of the Executive Director, email: DataClearance@ferc.gov, Phone: (202)
502-8663, fax: (202) 273-0873]. Comments on the requirements of this
rule may also be sent to the Office of Information and Regulatory
Affairs, Office of Management and Budget, Washington, DC 20503
[Attention: Desk Officer for the Federal Energy Regulatory Commission].
For security reasons, comments should be sent by email to OMB at oira_submission@omb.eop.gov. Please reference OMB Control No. 1902-0255,
FERC-920, and Docket No. RM12-3 in your submission.
V. Environmental Analysis
64. The Commission is required to prepare an Environmental
Assessment or an Environmental Impact Statement for any action that may
have a significant adverse effect on the human environment.\128\ The
actions taken here fall within categorical exclusions in the
Commission's regulations for information gathering, analysis, and
dissemination.\129\ Therefore, an environmental assessment is
unnecessary and has not been prepared in this rulemaking.
---------------------------------------------------------------------------
\128\ Regulations Implementing the National Environmental Policy
Act, Order No. 486, 52 FR 47897 (Dec. 17, 1987), FERC Stats. & Regs.
Preambles 1986-1990 ] 30,783 (1987).
\129\ 18 CFR 380.4(a)(5).
---------------------------------------------------------------------------
VI. Regulatory Flexibility Act
65. The Regulatory Flexibility Act of 1980 (RFA) \130\ generally
requires a description and analysis of final rules that will have
significant economic impact on a substantial number of small entities.
The RFA mandates consideration of regulatory alternatives that
accomplish the stated objectives of a proposed rule and that minimize
any significant economic impact on a substantial number of small
entities. The SBA's Office of Size Standards develops the numerical
definition of a small business.\131\ The SBA has established a size
standard for electric utilities, stating that a firm is small if,
including its affiliates, it is primarily engaged in the transmission,
generation and/or distribution of electric energy for sale and its
total electric output for the preceding twelve months did not exceed
4,000,000 MWh.\132\
---------------------------------------------------------------------------
\130\ 5 U.S.C. 601-612.
\131\ 13 CFR 121.101.
\132\ 13 CFR 121.201, Sector 22, Utilities & n.1.
---------------------------------------------------------------------------
66. As discussed in Order No. 2000,\133\ in making this
determination, the Commission is required to examine only the direct
compliance costs that a rulemaking imposes upon small businesses. It is
not required to consider indirect economic consequences, nor is it
required to consider costs that an entity incurs voluntarily.
---------------------------------------------------------------------------
\133\ See Regional Transmission Organizations, Order No. 2000,
65 FR 809 (Jan. 6, 2000), FERC Stats. & Regs. ] 31,089, at 31,237 &
n.754 (1999), order on reh'g, Order No. 2000-A, 65 FR 12,088 (Mar.
8, 2000), FERC Stats. & Regs. ] 31,092 (2000), aff'd sub nom. Pub.
Util. Dist. No. 1 of Snohomish, County Washington v. FERC, 272 F.3d
607, 348 U.S. App. DC 205 (DC Cir. 2001) (citing Mid-Tex Elec. Coop.
v. FERC, 773 F.2d 327 (DC Cir. 1985) (Commission need only consider
small entities ``that would be directly regulated''); Colorado State
Banking Bd. v. RTC, 926 F.2d 931 (10th Cir. 1991) (Regulatory
Flexibility Act not implicated where regulation simply added an
option for affected entities and did not impose any costs)).
---------------------------------------------------------------------------
67. For non-public utilities, the Commission exempts under the de
minimis market presence threshold non-public utilities that make
4,000,000 MWh or less of annual wholesale sales (based on an average of
the wholesale sales it made in the preceding three years).\134\ This de
minimis threshold excludes small, non-public utilities. Therefore, this
Final Rule will not have a significant economic impact on any small,
non-public utility.
---------------------------------------------------------------------------
\134\ Transparency Rule, FERC Stats. & Regs. ] 31,336 at P 54.
---------------------------------------------------------------------------
68. For public utilities, based on analysis of the EQR filings made
in the four quarters of 2011, there are 1,783 entities that currently
file an EQR, but given clearly identifiable affiliate relationships
that number is reduced to 1,215 entities. Of those, 97 reported more
than 4,000,000 MWh of wholesale sales in the EQR. Of the remaining
1,118 entities that reported less than 4,000,000 MWh of wholesales
sales in the EQR, 641 filed transactions in the EQR. The rest that
would be subject to this Final Rule, 477 entities, did not file
transactions in any quarter of 2011; we conclude that this Final Rule
will minimally affect them.
69. As for the remaining 641 entities, we note that there are two
types of companies among those currently filing EQRs that merit
additional consideration. First, there are investor-owned public
utilities that make both wholesale and retail sales. The SBA's
definition of a small utility is based on a utility's total electric
output for the preceding twelve months, which includes a public
utility's retail sales. However, our estimate in this section is based
on information available in the EQR, which includes annual wholesale
sales but not retail sales. If we were able to include retail sales, we
believe that most investor-owned public utilities that currently file
EQRs make more than 4,000,000 MWh annual wholesale and retail sales and
thus would not be classified as small. Second, there are power
marketers that often do not own or control generation or transmission
and may be affiliated with companies that are not primarily engaged in
the sale of electric energy (such as financial institutions or hedge
funds).\135\ However, information regarding whether a power marketer is
affiliated with another company is generally not included in an EQR
filing, making it difficult to determine the number of small entities
that are affiliated with a larger company, thereby leading to an
inflated estimate of the number of companies affected by this Final
Rule that are truly small.
---------------------------------------------------------------------------
\135\ Some of these such as Google, Occidental Chemical and
ONEOK may not qualify as small in their primary area of business and
are participating in the electric market as part of an overall
corporate strategy.
---------------------------------------------------------------------------
70. Furthermore, to ease the burden of implementation for all EQR
sellers, we will minimize the changes which EQR sellers will experience
because the Commission is adopting two options for filing EQRs: the Web
interface and XML. The estimated one-time implementation cost per EQR
seller is $1,434.50. We anticipate no change or a slight reduction in
the burden for the recurring quarterly EQR filings. In addition, small
entities generally have few or no transactions and corresponding
minimal recurring burden. We note that EQR sellers may request, on an
individual basis, waiver from the Commission's EQR reporting
requirements. Thus, we certify that this proposed rule will not have a
significant impact on a substantial number of small entities.
VII. Document Availability
71. 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 FERC's Home Page (https://www.ferc.gov) and in FERC's
Public Reference Room
[[Page 71299]]
during normal business hours (8:30 a.m. to 5:00 p.m. Eastern time) at
888 First Street NE., Room 2A, Washington DC 20426.
72. From FERC's Home Page on the Internet, this information is
available on eLibrary. The full text of this document is available on
eLibrary in PDF and Microsoft Word format for viewing, printing, and/or
downloading. To access this document in eLibrary, type the docket
number excluding the last three digits of this document in the docket
number field.
73. User assistance is available for eLibrary and the FERC's Web
site during normal business hours from FERC Online Support at (202)
502-6652 (toll free at 1-866-208-3676) or email at
ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 502-
8371, TTY (202) 502-8659. Email the Public Reference Room at
public.referenceroom@ferc.gov.
VIII. Effective Date and Congressional Notification
74. These regulations are effective April 1, 2013. The Commission
has determined, with the concurrence of the Administrator of the Office
of Information and Regulatory Affairs of OMB, that this rule is not a
``major rule'' as defined in section 351 of the Small Business
Regulatory Enforcement Fairness Act of 1996.
List of Subjects in 18 CFR Part 35
Electric power rates, Electric utilities, Reporting and
recordkeeping requirements.
By direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
In consideration of the foregoing, the Commission amends 18 CFR
part 35 as follows:
PART 35--FILIING OF RATE SCHEDULES AND TARIFFS
0
1. The authority citation for Part 35 continues to read as follows:
Authority: 16 U.S.C. 791a-825r, 2601-2645; 31 U.S.C. 9701; 42
U.S.C. 7101-7352.
0
2. Section 35.10b is amended by revising the second sentence to read as
follow:
Sec. 35.10b Electric Quality Reports.
* * * Electric Quarterly Reports must be prepared in conformance
with the Commission's guidance posted on the FERC Web site (https://www.ferc.gov).
Note: The following appendices A and B will not appear in the Code
of Federal Regulations:
Appendix A: Abbreviated Names of Commenters
------------------------------------------------------------------------
Commenters Abbreviation
------------------------------------------------------------------------
California Independent System Operator CAISO
Corporation.
Edison Electric Institute.............. EEI
Electric Power Supply Association...... EPSA
Energy Compliance Consulting, LLC...... Energy Compliance Consulting
Energy Services Providers, Inc.,....... Energy Services Providers
Connecticut Gas & Electric, Inc., and ...............................
Massachusetts Gas & Electric Inc..
Idaho Power Company.................... Idaho Power
Links Technology....................... Links
Solutions, Inc......................... Technology Solutions
Pacific Gas and Electric Company....... Pacific Gas and Electric
Southern California Edison Company..... Southern California Edison
------------------------------------------------------------------------
Appendix B: EQR Data Dictionary
Electric Quarterly Report Data Dictionary Version 2.1 (issued November
15, 2012) \136\
---------------------------------------------------------------------------
\136\ This version of Appendix B replaces the version that was
included with Revisions to Electric Quarterly Report Filing Process,
Order No. 770, 141 FERC ] 61,120 (2012).
EQR Data Dictionary
----------------------------------------------------------------------------------------------------------------
Field No.
--------------------------- Field Required Value Definition
Old New
----------------------------------------------------------------------------------------------------------------
ID Data
----------------------------------------------------------------------------------------------------------------
1........... 1........... Filer Unique [check]........... FS (where (Seller)--An identifier
Identifier. ``'' is (e.g., ``FS1'',
an 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.
[[Page 71300]]
1........... 1........... Filer Unique [check]........... FA1............... (Agent)--An identifier
Identifier. (i.e., ``FA1'') used
to designate a record
containing Agent
identification
information in a comma-
delimited (csv) file
that is imported into
the EQR filing. Only
one record with the
FA1 identifier may be
imported into an EQR
for a given quarter.
2........... 2........... Company Name....... [check]........... 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).
2........... 2........... Company Name....... [check]........... Unrestricted text (Agent)--The name of
(100 characters). the entity completing
the EQR filing. The
Agent's Company Name
need not be the name
of the company under
Commission
jurisdiction.
3........... X........... ................... .................. .................. .......................
3........... Company Identifier. [check]........... A 7-digit integer (Seller)--Identifier
proceeded by the obtained through the
letter ``C''. Commission's Company
Registration system.
3........... 4........... Contact Name....... [check]........... 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).
3........... 4........... Contact Name....... [check]........... Unrestricted text (Agent)--Name of the
(50 characters). contact for the Agent,
usually the person who
prepares the filing.
4........... 5........... Contact Title...... [check]........... Unrestricted text Title of contact
(50 characters). identified in Field
Number 4.
5........... 6........... Contact Address.... [check]........... Unrestricted text. Street address for
contact identified in
Field Number 4.
6........... 7........... Contact City....... [check]........... Unrestricted text City for the contact
(30 characters). identified in Field
Number 4.
7........... 8........... Contact State...... [check]........... Unrestricted text Two character state or
(2 characters). province abbreviations
for the contact
identified in Field
Number 4.
8........... 9........... Contact Zip........ [check]........... Unrestricted text Zip code for the
(10 characters). contact identified in
Field Number 4.
9........... 10.......... Contact Country [check]........... CA--Canada........ Country (USA, Canada,
Name. MX--Mexico........ Mexico, or United
US--United States. Kingdom) for contact
UK--United Kingdom address identified in
Field Number 4.
10.......... 11.......... Contact Phone...... [check]........... Unrestricted text Phone number of contact
(20 characters). identified in Field
Number 4.
11.......... 12.......... Contact E-Mail..... [check]........... Unrestricted text. E-mail address of
contact identified in
Field Number 4.
12.......... 13.......... Transactions [check]........... Y (Yes)........... Filers should indicate
Reported to Index N (No)............ whether they have
Price Publisher(s). reported their sales
transactions to index
price publisher(s). If
they have, filers
should indicate
specifically which
index publisher(s) in
Field Number 73.
13.......... 14.......... Filing Quarter..... [check]........... YYYYMM............ A six digit reference
number used by the EQR
software to indicate
the quarter and year
of the filing for the
purpose of importing
data from csv files.
The first 4 numbers
represent the year
(e.g., 2007). The last
2 numbers represent
the last month of the
quarter (e.g., 03=1st
quarter; 06=2nd
quarter, 09=3rd
quarter, 12=4th
quarter).
----------------------------------------------------------------------------------------------------------------
EQR Data Dictionary Contract Data
----------------------------------------------------------------------------------------------------------------
14.......... 15.......... Contract Unique ID. [check]........... An integer An identifier beginning
proceeded by the with the letter ``C''
letter ``C'' and followed by a
(only used when number (e.g., ``C1'',
importing ``C2'') used to
contract data). 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.......... 16.......... Seller Company Name [check]........... Unrestricted text The name of the company
(100 characters). that is authorized to
make sales as
indicated in the
company's FERC
tariff(s). This name
must match the name
provided as a Seller's
``Company Name'' in
Field Number 2 of the
ID Data (Seller Data).
[[Page 71301]]
16.......... 17.......... Customer Company [check]........... Unrestricted text The name of the
Name. (70 characters). counterparty.
17.......... X........... ................... .................. .................. .......................
17.......... 18.......... Contract Affiliate. [check]........... Y (Yes)........... The customer is an
N (No)............ 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.
18.......... 19.......... FERC Tariff [check]........... 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.
19.......... 20.......... Contract Service [check]........... 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.
20.......... 21.......... Contract Execution [check]........... YYYYMMDD.......... The date the contract
Date. was signed. If the
parties signed on
different dates, use
the most recent date
signed.
21.......... 22.......... Commencement Date [check]........... YYYYMMDD.......... The date the terms of
of Contract Terms. the contract reported
in fields 18, 23 and
25 through 44 (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 44 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.
22.......... 23.......... Contract If specified in YYYYMMDD.......... The date that the
Termination Date. the contract. contract expires.
23.......... 24.......... Actual Termination If contract YYYYMMDD.......... The date the contract
Date Extension. terminated. actually terminates.
24.......... 25.......... Extension Provision [check]........... Unrestricted text. Description of terms
Description. that provide for the
continuation of the
contract.
25.......... 26.......... Class Name......... [check]........... .................. See definitions of each
class name below.
25.......... 26.......... Class Name......... [check]........... F--Firm........... For transmission sales,
a service or product
that always has
priority over non-firm
service. For power
sales, a service or
product that is not
interruptible for
economic reasons.
25.......... 26.......... Class Name......... [check]........... NF--Non-firm...... For transmission sales,
a service that is
reserved and/or
scheduled on an as-
available basis and is
subject to curtailment
or interruption at a
lesser priority
compared to Firm
service. For an energy
sale, a service or
product for which
delivery or receipt of
the energy may be
interrupted for any
reason or no reason,
without liability on
the part of either the
buyer or seller.
[[Page 71302]]
25.......... 26.......... Class Name......... [check]........... UP--Unit Power Designates a dedicated
Sale. sale of energy and
capacity from one or
more than one
specified generation
unit(s).
25.......... 26.......... Class Name......... [check]........... N/A--Not To be used only when
Applicable. the other available
Class Names do not
apply.
26.......... 27.......... Term Name.......... [check]........... LT--Long Term..... Contracts with
ST--Short Term.... durations of one year
N/A--Not or greater are long-
Applicable. term. Contracts with
shorter durations are
short-term.
27.......... 28.......... Increment Name..... [check]........... .................. See definitions for
each increment below.
27.......... 28.......... Increment Name..... [check]........... H--Hourly......... Terms of the contract
(if specifically noted
in the contract) set
for up to 6
consecutive hours (<=
6 consecutive hours).
27.......... 28.......... Increment Name..... [check]........... D--Daily.......... Terms of the contract
(if specifically noted
in the contract) set
for more than 6 and up
to 60 consecutive
hours (>6 and <= 60
consecutive hours).
27.......... 28.......... Increment Name..... [check]........... W--Weekly......... Terms of the contract
(if specifically noted
in the contract) set
for over 60
consecutive hours and
up to 168 consecutive
hours (>60 and <= 168
consecutive hours).
27.......... 28.......... Increment Name..... [check]........... M--Monthly........ Terms of the contract
(if specifically noted
in the contract) set
for more than 168
consecutive hours up
to, but not including,
one year (>168
consecutive hours and
< 1 year).
27.......... 28.......... Increment Name..... [check]........... Y--Yearly......... Terms of the contract
(if specifically noted
in the contract) set
for one year or more
(>= 1 year).
27.......... 28.......... Increment Name..... [check]........... N/A--Not Terms of the contract
Applicable. do not specify an
increment.
28.......... 29.......... Increment Peaking [check]........... .................. See definitions for
Name. each increment peaking
name below.
28.......... 29.......... Increment Peaking [check]........... 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.
28.......... 29.......... Increment Peaking [check]........... 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.
28.......... 29.......... Increment Peaking [check]........... 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.
28.......... 29.......... Increment Peaking [check]........... N/A--Not To be used only when
Name. Applicable. the increment peaking
name is not specified
in the contract.
29.......... 30.......... Product Type Name.. [check]........... .................. See definitions for
each product type
below.
29.......... 30.......... Product Type Name.. [check]........... CB--Cost Based.... Energy or capacity sold
under a FERC-approved
cost-based rate
tariff.
29.......... 30.......... Product Type Name.. [check]........... CR--Capacity An agreement under
Reassignment. which a transmission
provider sells,
assigns or transfers
all or portion of its
rights to an eligible
customer.
29.......... 30.......... Product Type Name.. [check]........... MB--Market Based.. Energy or capacity sold
under the seller's
FERC-approved market-
based rate tariff.
29.......... 30.......... Product Type Name.. [check]........... T--Transmission... The product is sold
under a FERC-approved
transmission tariff.
29.......... 30.......... Product Type Name.. [check]........... Other............. The product cannot be
characterized by the
other product type
names.
30.......... 31.......... Product Name....... [check]........... See Product Name Description of product
Table, Appendix A. being offered.
31.......... 32.......... Quantity........... If specified in Number with up to Quantity for the
the contract. 4 decimals. contract product
identified.
32.......... 33.......... Units.............. If specified in See Units Table, Measure stated in the
the contract. Appendix E. contract for the
product sold.
33.......... 34.......... Rate............... One of four rate Number with up to The charge for the
fields (34, 35, 4 decimals. product per unit as
36, or 37) must stated in the
be included. contract.
34.......... 35.......... Rate Minimum....... One of four rate Number with up to Minimum rate to be
fields (34, 35, 4 decimals. charged per the
36, or 37) must contract, if a range
be included. is specified.
35.......... 36.......... Rate Maximum....... One of four rate Number with up to Maximum rate to be
fields (34, 35, 4 decimals. charged per the
36, or 37) must contract, if a range
be included. is specified.
[[Page 71303]]
36.......... 37.......... Rate Description... One of four rate Unrestricted text. Text description of
fields (34, 35, rate. If the rate is
36, or 37) must currently available on
be 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.
37.......... 38.......... Rate Units......... If specified in See Rate Units Measure stated in the
the contract. Table, Appendix F. contract for the
product sold.
38.......... 39.......... Point of Receipt If specified in See Balancing The registered NERC
Balancing the contract. Authority Table, Balancing Authority
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.
39.......... 40.......... Point of Receipt If specified in Unrestricted text The specific location
Specific Location the contract. (50 characters). at which the product
(PORSL). If ``HUB'' is is received if
selected for designated in the
PORCA, see Hub contract. If receipt
Table, Appendix C. 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.
40.......... 41.......... Point of Delivery If specified in See Balancing The registered NERC
Balancing the contract. Authority Table, Balancing Authority
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.
41.......... 42.......... Point of Delivery If specified in Unrestricted text The specific location
Specific Location the contract. (50 characters). at which the product
(PODSL). If ``HUB'' is is delivered if
selected for designated in the
PODCA, see Hub contract. If receipt
Table, Appendix C. occurs at a trading
hub, a standardized
hub name must be used.
42.......... 43.......... Begin Date......... If specified in YYYYMMDDHHMM...... First date for the sale
the contract. of the product at the
rate specified.
43.......... 44.......... End Date........... If specified in YYYYMMDDHHMM...... Last date for the sale
the contract. of the product at the
rate specified.
45.......... X........... ................... .................. .................. .......................
----------------------------------------------------------------------------------------------------------------
[[Page 71304]]
Transaction Data
----------------------------------------------------------------------------------------------------------------
44.......... 45.......... Transaction Unique [check]........... An integer An identifier beginning
ID. proceeded by the with the letter ``T''
letter ``T'' and followed by a
(only used when number (e.g., ``T1'',
importing ``T2'') used to
transaction data). 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.
45.......... 46.......... Seller Company Name [check]........... Unrestricted text The name of the company
(100 Characters). that is authorized to
make sales as
indicated in the
company's FERC
tariff(s). This name
must match the name
provided as a Seller's
``Company Name'' in
Field 2 of the ID Data
(Seller Data).
46.......... 47.......... Customer Company [check]........... Unrestricted text The name of the
Name. (70 Characters). counterparty.
49.......... X........... ................... .................. .................. .......................
47.......... 48.......... FERC Tariff [check]........... 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.
48.......... 49.......... Contract Service [check]........... 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.
49.......... 50.......... Transaction Unique [check]........... Unrestricted text Unique reference number
Identifier. (24 Characters). assigned by the seller
for each transaction.
50.......... 51.......... Transaction Begin [check]........... YYYYMMDDHHMM (csv First date and time the
Date. import); product is sold during
MMDDYYYYHHMM the quarter.
(manual entry).
51.......... 52.......... Transaction End [check]........... YYYYMMDDHHMM (csv Last date and time the
Date. import); product is sold during
MMDDYYYYHHMM the quarter.
(manual entry).
52.......... 53.......... Trade Date......... [check]........... YYYYMMDD (csv The date upon which the
import); MMDDYYYY parties made the
(manual entry). legally binding
agreement on the price
of a transaction.
53.......... 54.......... Exchange/Brokerage .................. See Exchange/ If a broker service is
Service. Brokerage Service used to consummate or
Table, Appendix H. effectuate a
transaction, the term
``Broker'' shall be
selected from the
Commission-provided
list. If an exchange
is used, the specific
exchange that is used
shall be selected from
the Commission-
provided list.
54.......... 55.......... Type of Rate....... [check]........... .................. See type of rate
definitions below.
54.......... 55.......... Type of Rate....... [check]........... Fixed............. A fixed charge per unit
of consumption.
54.......... 55.......... Type of Rate....... [check]........... Formula........... A calculation of a rate
based upon a formula
that does not contain
an index component.
54.......... 55.......... Type of Rate....... [check]........... Electric Index.... A calculation of a rate
based upon an index or
a formula that
contains an index
component.
54.......... 55.......... Type of Rate....... [check]........... RTO/ISO........... A rate that is based on
an RTO/ISO published
price or formula that
contains an RTO/ISO
price component.
55.......... 56.......... Time Zone.......... [check]........... See Time Zone The time zone in which
Table, Appendix D. the sales will be made
under the contract.
56.......... 57.......... Point of Delivery [check]........... See Balancing The registered NERC
Balancing Authority Table, Balancing Authority
Authority (PODBA). Appendix B. (formerly called NERC
Control Area)
abbreviation used in
OASIS applications.
[[Page 71305]]
57.......... 58.......... Point of Delivery [check]........... Unrestricted text The specific location
Specific Location (50 characters). at which the product
(PODSL). If ``HUB'' is is delivered. If
selected for receipt occurs at a
PODBA, see Hub trading hub, a
Table, Appendix C. standardized hub name
must be used.
58.......... 59.......... Class Name......... [check]........... .................. See class name
definitions below.
58.......... 59.......... Class Name......... [check]........... F--Firm........... A sale, service or
product that is not
interruptible for
economic reasons.
58.......... 59.......... Class Name......... [check]........... NF--Non-firm...... A sale for which
delivery or receipt of
the energy may be
interrupted for any
reason or no reason,
without liability on
the part of either the
buyer or seller.
58.......... 59.......... Class Name......... [check]........... UP--Unit Power Designates a dedicated
Sale. sale of energy and
capacity from one or
more than one
specified generation
unit(s).
58.......... 59.......... Class Name......... [check]........... 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.......... 59.......... Class Name......... [check]........... N/A--Not To be used only when
Applicable; LT-- the other available
Long Term. class names do not
apply.
59.......... 60.......... Term Name.......... [check]........... ST--Short Term; N/ Power sales
A--Not Applicable. transactions with
durations of one year
or greater are long-
term. Transactions
with shorter durations
are short-term.
60.......... 61.......... Increment Name..... [check]........... .................. See increment name
definitions below.
60.......... 61.......... Increment Name..... [check]........... H--Hourly......... Terms of the particular
sale set for up to 6
consecutive hours (<=
6 consecutive hours)
Includes LMP based
sales in ISO/RTO
markets.
60.......... 61.......... Increment Name..... [check]........... D--Daily.......... Terms of the particular
sale set for more than
6 and up to 60
consecutive hours (>6
and <= 60 consecutive
hours). Includes sales
over a peak or off-
peak block during a
single day.
60.......... 61.......... Increment Name..... [check]........... W--Weekly......... Terms of the particular
sale set for over 60
consecutive hours and
up to 168 consecutive
hours (>60 and <= 168
consecutive hours).
Includes sales for a
full week and sales
for peak and off-peak
blocks over a
particular week.
60.......... 61.......... Increment Name..... [check]........... M--Monthly........ Terms of the particular
sale set for set for
more than 168
consecutive hours up
to, but not including,
one year (>168
consecutive hours and
< 1 year). Includes
sales for full month
or multi-week sales
during a given month.
60.......... 61.......... Increment Name..... [check]........... 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.......... 61.......... Increment Name..... [check]........... N/A--Not To be used only when
Applicable. other available
increment names do not
apply.
61.......... 62.......... Increment Peaking [check]........... .................. See definitions for
Name. increment peaking
below.
61.......... 62.......... Increment Peaking [check]........... FP--Full Period... The product described
Name. was sold during Peak
and Off-Peak hours.
61.......... 62.......... Increment Peaking [check]........... 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.......... 62.......... Increment Peaking [check]........... 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.......... 62.......... Increment Peaking [check]........... N/A--Not To be used only when
Name. Applicable. the other available
increment peaking
names do not apply.
62.......... 63.......... Product Name....... [check]........... See Product Names Description of product
Table, Appendix A. being offered.
63.......... 64.......... Transaction [check]........... Number with up to The quantity of the
Quantity. 4 decimals. product in this
transaction.
[[Page 71306]]
64.......... 65.......... Price.............. [check]........... Number with up to Actual price charged
6 decimals. for the product per
unit. The price
reported cannot be
averaged or otherwise
aggregated.
65.......... 66.......... Rate Units......... [check]........... See Rate Units Measure appropriate to
Table, Appendix F. the price of the
product sold.
66.......... 67.......... Standardized [check]........... Number with up to For product names
Quantity. 4 decimals. energy, capacity, and
booked out power only.
Specify the quantity
in MWh if the product
is energy or booked
out power and specify
the quantity in MW if
the product is
capacity.
67.......... 68.......... Standardized Price. [check]........... Number with up to For product names
6 decimals. energy, capacity, and
booked out power only.
Specify the price in $/
MWh if the product is
energy or booked out
power and specify the
price in $/MW-month if
the product is
capacity.
68.......... 69.......... Total Transmission [check]........... Number with up to Payments received for
Charge. 2 decimals. transmission services
when explicitly
identified.
69.......... 70.......... Total Transaction [check]........... Number with up to Transaction Quantity
Charge. 2 decimals. (Field 64) times Price
(Field 65) plus Total
Transmission Charge
(Field 69).
----------------------------------------------------------------------------------------------------------------
Index Reporting Data
----------------------------------------------------------------------------------------------------------------
70.......... 71.......... Filer Unique [check]........... FS (where The ``FS'' seller
Identifier. ``'' is number from the ID
an integer). Data table
corresponding to the
index reporting
company.
71.......... 72.......... Seller Company Name [check]........... Unrestricted text The name of the company
(100 characters). that is authorized to
make sales as
indicated in the
company's FERC
tariff(s). This name
must match the name
provided as a Seller's
``Company Name'' in
Field Number 2 of the
ID Data (Seller Data).
72.......... 73.......... Index Price [check]........... If ``Yes'' is The index price
Publisher(s) To selected for publisher(s) to which
Which Sales Field 13, see sales transactions
Transactions Have Index Price have been reported.
Been Reported. Publisher,
Appendix G.
73.......... 74.......... Transactions [check]........... Unrestricted text Description of the
Reported. (100 characters). types of transactions
reported to the index
publisher identified
in this record.
----------------------------------------------------------------------------------------------------------------
e-Tag Data
----------------------------------------------------------------------------------------------------------------
74.......... 75.......... e-Tag ID........... If an e-Tag ID was Unrestricted text The e-Tag ID contains:
used to schedule (30 Characters). The Source Balancing
the EQR Authority where the
transaction. generation is located;
The Purchasing-Selling
Balancing Authority
Entity Code; the e-Tag
Code; and the Sink
Balancing Authority.
75.......... 76.......... e-Tag Begin Date... If an e-Tag ID was YYYYMMDD (csv The first date the
used to schedule import); MMDDYYYY transaction is
the EQR (manual entry). scheduled using the e-
transaction. Tag ID reported in
Field Number 75. Begin
Date must not be
before the Transaction
Begin Date specified
in Field Number 51 and
must be reported in
the same time zone
specified in Field
Number 56.
76.......... 77.......... e-Tag End Date..... If an e-Tag ID was YYYYMMDD (csv The last date the
used to schedule import); MMDDYYYY transaction is
the EQR (manual entry). scheduled using the e-
transaction. Tag ID reported in
Field Number 75. End
Date must not be after
the Transaction End
Date specified in
Field Number 52 and
must be reported in
the same time zone
specified in Field
Number 56.
77.......... 78.......... Transaction Unique If an e-Tag ID was Unrestricted text Unique reference number
Identifier. used to schedule (24 Characters). assigned by the seller
the EQR for each transaction
transaction. that must be the same
as reported in Field
Number 50.
----------------------------------------------------------------------------------------------------------------
[[Page 71307]]
EQR Data Dictionary
[Appendix A. Product Names]
----------------------------------------------------------------------------------------------------------------
Contract Transaction
Product name product product Definition
----------------------------------------------------------------------------------------------------------------
BLACK START SERVICE............. [check] [check] 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................ ............... [check] Energy or capacity contractually committed
bilaterally for delivery but not actually
delivered due to some offsetting or
countervailing trade (Transaction only).
CAPACITY........................ [check] [check] A quantity of demand that is charged on a $/
KW or $/MW basis.
CUSTOMER CHARGE................. [check] [check] Fixed contractual charges assessed on a per
customer basis that could include billing
service.
DIRECT ASSIGNMENT FACILITIES [check] ............... Charges for facilities or portions of
CHARGE. facilities that are constructed or used for
the sole use/benefit of a particular
customer.
EMERGENCY ENERGY................ [check] ............... Contractual provisions to supply energy or
capacity to another entity during critical
situations.
ENERGY.......................... [check] [check] A quantity of electricity that is sold or
transmitted over a period of time.
ENERGY IMBALANCE................ [check] [check] 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........................ [check] [check] 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..................... [check] [check] Charge based on the cost or amount of fuel
used for generation.
GENERATOR IMBALANCE............. [check] [check] 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........... [check] [check] Services provided for bundled transmission,
ancillary services and energy under
contracts effective prior to Order No.
888's OATTs.
INTERCONNECTION AGREEMENT....... [check] ............... 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............ [check] ............... Agreement to participate and be subject to
rules of a system operator.
MUST RUN AGREEMENT.............. [check] ............... An agreement that requires a unit to run.
NEGOTIATED-RATE TRANSMISSION.... [check] [check] Transmission performed under a negotiated
rate contract (applies only to merchant
transmission companies).
NETWORK......................... [check] ............... Transmission service under contract
providing network service.
NETWORK OPERATING AGREEMENT..... [check] ............... 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........................... [check] [check] Product name not otherwise included.
POINT-TO-POINT AGREEMENT........ [check] ............... Transmission service under contract between
specified Points of Receipt and Delivery.
REACTIVE SUPPLY & VOLTAGE [check] [check] Production or absorption of reactive power
CONTROL. to maintain voltage levels on transmission
systems (Ancillary Service).
REAL POWER TRANSMISSION LOSS.... [check] [check] The loss of energy, resulting from
transporting power over a transmission
system.
REASSIGNMENT AGREEMENT.......... [check] ............... Transmission capacity reassignment
agreement.
REGULATION & FREQUENCY RESPONSE. [check] [check] 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............ [check] [check] 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.)
[[Page 71308]]
SCHEDULE SYSTEM CONTROL & [check] [check] Scheduling, confirming and implementing an
DISPATCH. 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................ [check] [check] 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............ [check] [check] 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..... [check] ............... 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.................. [check] [check] 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... [check] ............... The agreement that establishes the terms and
conditions under which a transmission owner
transfers operational control over
designated transmission facilities.
UPLIFT.......................... [check] [check] A make-whole payment by an RTO/ISO to a
utility.
----------------------------------------------------------------------------------------------------------------
EQR Data Dictionary
[Appendix B. Balancing Authority]
------------------------------------------------------------------------
Balancing authority Abbreviation Outside US*
------------------------------------------------------------------------
AESC, LLC--Wheatland CIN....... AEWC ...............
Alabama Electric Cooperative, AEC ...............
Inc..
Alberta Electric System AESO [check]
Operator.
Alliant Energy Corporate ALTE ...............
Services, LLC--East.
Alliant Energy Corporate ALTW ...............
Services, LLC--West.
Ameren Transmission. Illinois.. AMIL ...............
Ameren Transmission. Missouri.. AMMO ...............
American Transmission Systems, FE ...............
Inc..
Aquila Networks--Kansas........ WPEK ...............
Aquila Networks--Missouri MPS ...............
Public Service.
Aquila Networks--West Plains WPEC ...............
Dispatch.
Arizona Public Service Company. AZPS ...............
Associated Electric AECI ...............
Cooperative, Inc..
Avista Corp.................... AVA ...............
Batesville Balancing Authority. BBA ...............
BC Hydro T & D--Grid Operations BCHA [check]
Big Rivers Electric Corp....... BREC ...............
Board of Public Utilities...... KACY ...............
Bonneville Power Administration BPAT ...............
Transmission.
British Columbia Transmission BCTC [check]
Corporation.
California Independent System CISO ...............
Operator.
Carolina Power & Light Company-- CPLW ...............
CPLW.
Carolina Power and Light CPLE ...............
Company--East.
Central and Southwest.......... CSWS ...............
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 ...............
City Utilities of Springfield.. SPRM ...............
Cleco Power LLC................ CLEC ...............
Columbia Water & Light......... CWLD ...............
Comision Federal de CFE [check]
Electricidad.
Comision Federal de CFEN [check]
Electricidad.
Constellation Energy Control GRIF ...............
and Dispatch.
Constellation Energy Control PUPP ...............
and Dispatch--Arkansas.
[[Page 71309]]
Constellation Energy Control BUBA ...............
and Dispatch--City of Benton,
AR.
Constellation Energy Control DERS ...............
and Dispatch--City of Ruston,
LA.
Constellation Energy Control CNWY ...............
and Dispatch--Conway, Arkansas.
Constellation Energy Control GRMA ...............
and Dispatch--Gila River.
Constellation Energy Control GWA ...............
and Dispatch--Glacier Wind
Energy.
Constellation Energy Control HGMA ...............
and Dispatch--Harquehala.
Constellation Energy Control DENL ...............
and Dispatch--North Little
Rock, AK.
Constellation Energy Control OMLP ...............
and Dispatch--Osceola
Municipal Light.
Constellation Energy Control PLUM ...............
and Dispatch--Plum Point.
Constellation Energy Control REDM ...............
and Dispatch--Red Mesa.
Constellation Energy Control WMUC ...............
and Dispatch--West Memphis,
Arkansas.
Dairyland Power Cooperative.... DPC ...............
DECA, LLC--Arlington Valley.... DEAA ...............
Duke Energy Corporation........ DUK ...............
East Kentucky Power EKPC ...............
Cooperative, Inc..
El Paso Electric............... EPE ...............
Electric Energy, Inc........... EEI ...............
Empire District Electric Co., EDE ...............
The.
Entergy........................ EES ...............
ERCOT ISO...................... ERCO ...............
Florida Municipal Power Pool... FMPP ...............
Florida Power & Light.......... FPL ...............
Florida Power Corporation...... FPC ...............
Gainesville Regional Utilities. GVL ...............
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 [check]
Idaho Power Company............ IPCO ...............
Imperial Irrigation District... IID ...............
Indianapolis Power & Light IPL ...............
Company.
ISO New England Inc............ ISNE ...............
JEA............................ JEA ...............
Kansas City Power & Light, Co.. KCPL ...............
Lafayette Utilities System..... LAFA ...............
LG&E Energy Transmission LGEE ...............
Services.
Lincoln Electric System........ LES ...............
Los Angeles Department of Water LDWP ...............
and Power.
Louisiana Energy & Power LEPA ...............
Authority.
Louisiana Generating, LLC...... LAGN ...............
Louisiana Generating, LLC--City CWAY ...............
of Conway.
Louisiana Generating, LLC--City WMU ...............
of West Memphis.
Louisiana Generating, LLC-- NLR ...............
North Little Rock.
Madison Gas and Electric MGE ...............
Company.
Manitoba Hydro Electric Board, MHEB [check]
Transmission Services.
Michigan Electric Coordinated MECS ...............
System.
Michigan Electric Coordinated CONS ...............
System--CONS.
Michigan Electric Coordinated DECO ...............
System--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 System Operator.. NBSO [check]
New Horizons Electric NHC1 ...............
Cooperative.
New York Independent System NYIS ...............
Operator.
Northern Indiana Public Service NIPS ...............
Company.
Northern States Power Company.. NSP ...............
NorthWestern Energy............ NWMT ...............
Ohio Valley Electric OVEC ...............
Corporation.
Oklahoma Gas and Electric...... OKGE ...............
Ontario--Independent ONT [check]
Electricity System Operator.
OPPDCA/TP...................... OPPD ...............
Otter Tail Power Company....... OTP ...............
[[Page 71310]]
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 PSCO ...............
Colorado.
Public Service Company of New PNM ...............
Mexico.
Puget Sound Energy Transmission PSEI ...............
Reedy Creek Improvement RC ...............
District.
Sacramento Municipal Utility SMUD ...............
District.
Salt River Project............. SRP ...............
Santee Cooper.................. SC ...............
SaskPower Grid Control Centre.. SPC [check]
Seattle City Light............. SCL ...............
Seminole Electric Cooperative.. SEC ...............
Sierra Pacific Power Co.-- SPPC ...............
Transmission.
South Carolina Electric & Gas SCEG ...............
Company.
South Mississippi Electric SME ...............
Power Association.
South Mississippi Electric SMEE ...............
Power Association.
Southeastern Power SEHA ...............
Administration--Hartwell.
Southeastern Power SERU ...............
Administration--Russell.
Southeastern Power SETH ...............
Administration--Thurmond.
Southern Company Services, Inc. SOCO ...............
Southern Illinois Power SIPC ...............
Cooperative.
Southern Indiana Gas & Electric SIGE ...............
Co..
Southern Minnesota Municipal SMP ...............
Power Agency.
Southwest Power Pool........... SWPP ...............
Southwestern Power SPA ...............
Administration.
Southwestern Public Service SPS ...............
Company.
Sunflower Electric Power SECI ...............
Corporation.
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 ...............
Utilities Commission, City of NSB ...............
New Smyrna Beach.
Westar Energy--MoPEP Cities.... MOWR ...............
Western Area Power WACM ...............
Administration--Colorado-
Missouri.
Western Area Power WALC ...............
Administration--Lower Colorado.
Western Area Power WAUE ...............
Administration--Upper Great
Plains East.
Western Area Power WAUW ...............
Administration--Upper Great
Plains West.
Western Farmers Electric WFEC ...............
Cooperative.
Western Resources dba Westar WR ...............
Energy.
Wisconsin Energy Corporation... WEC ...............
Wisconsin Public Service WPS ...............
Corporation.
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.
[[Page 71311]]
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.
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.
------------------------------------------------------------------------
[[Page 71312]]
EQR Data Dictionary
[Appendix G. Index Price Publisher]
------------------------------------------------------------------------
Index price publisher abbreviation Index price publisher
------------------------------------------------------------------------
AM.................................. Argus Media.
EIG................................. Energy Intelligence Group, Inc.
IP.................................. Intelligence Press.
P................................... Platts.
B................................... Bloomberg.
DJ.................................. Dow Jones.
Pdx................................. Powerdex.
SNL................................. SNL Energy.
------------------------------------------------------------------------
EQR Data Dictionary
[Appendix H. Exchange/Broker Services]
------------------------------------------------------------------------
Exchange/brokerage service Definition
------------------------------------------------------------------------
BROKER.............................. A broker was used to consummate or
effectuate the transaction.
ICE................................. Intercontinental Exchange.
NYMEX............................... New York Mercantile Exchange.
------------------------------------------------------------------------
[FR Doc. 2012-28230 Filed 11-29-12; 8:45 am]
BILLING CODE 6717-01-P
