Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 26091 

1We are also proposing to change three field 

names to reflect terminology adopted by the North 

American Electric Reliability Corporation (NERC) in 

2005. We are not proposing any other changes to 

field names. All other proposed changes are to the 

definitions of terms and values used for EQR filings. 

2Revised Public Utility Filing Requirements, 

Order No. 2001, 67 FR 31043, FERC Stats. & Regs. 

¶ 31,127, reh’g denied, Order No. 2001–A, 100 

FERC ¶ 61,074, reconsideration and clarification 

denied, Order No. 2001–B, 100 FERC ¶ 61,342, 

order directing filings, Order No. 2001–C, 101 FERC 

¶ 61,314 (2002). 

Environmental Impact Statement (EIS) 

for the Guardian Expansion and 

Extension Project, proposed by 

Guardian Pipeline, L.L.C. Issuance of 

the draft EIS began a 45-day public 

comment period which will end on May 

29, 2007. In addition to accepting 

written comments on the draft EIS, the 

Commission staff will be hosting public 

comment meetings in the project area to 

accept oral comments as listed in the 

following table. 

Public meeting date and time Location 

Tuesday, May 15, 2007 at 7 p.m. (CST) ........................... Olympia Resort and Conference Center, 1350 Royale Mile Road, Oconomowoc, WI 

53066, Phone: (262) 369–4999. 

Wednesday, May 16, 2007 at 7 p.m. (CST) ...................... Bauer Ramada Plaza Hotel, 1 North Main St., Fond du Lac, WI 54935, Phone: (920) 

923–3000. 

Thursday, May 17, 2007 at 7 p.m. (CST) .......................... Regency Suites and Conference Center Downtown Green Bay, 333 Main St., Green 

Bay, WI 54301, Phone: (920) 432–4555. 

Comment Procedure 

Instructions for submitting written 

comments are included in the draft EIS 

and the Notice of Availability that were 

issued on April 13, 2007. These 

documents can be found on the FERC 

Internet Web site as discussed below. 

Oral comments presented at the public 

comment meetings will be given the 

same consideration as written 

comments received by mail before the 

close of the public comment period on 

May 29, 2007. 

As with previous public meetings on 

the Guardian Expansion and Extension 

Project, attendees will be asked to 

provide their name and address so that 

any project-related environmental 

information issued by the Commission 

may be mailed to all attendees. 

Additionally, those wishing to provide 

oral comments will be asked to put their 

name on a Speakers List. Depending on 

the number of individuals wishing to 

provide oral comments, speakers may be 

asked to limit their presentations to 5 

minutes in order that all speakers may 

be accommodated. Transcripts of the 

public comment meetings will be 

prepared and placed into the FERC’s 

public record. 

Additional information about the 

project is available from the 

Commission’s Office of External Affairs, 

at 1–866–208–FERC or on the FERC 

Internet Web site (http://www.ferc.gov) 

using the eLibrary link. Click on the 

eLibrary link, click on ‘‘General Search’’

and enter the docket number excluding 

the last three digits in the Docket 

Number field. Be sure you have selected 

an appropriate date range. For 

assistance, please contact FERC Online 

Support at 

FERCOnlineSupport@ferc.gov or toll 

free at 1–866–208–3676, or for TTY, 

contact (202) 502–8659. The eLibrary 

link on the FERC Internet Web site also 

provides access to the texts of formal 

documents issued by the Commission, 

such as orders, notices, and 

rulemakings. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. E7–8703 Filed 5–7–07; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. RM01–8–006] 

Revised Public Utility Filing 

Requirements for Electric Quarterly 

Reports 

April 23, 2007. 

AGENCY: Federal Energy Regulatory 

Commission. 

ACTION: Notice Seeking Comments on 

Proposed Electric Quarterly Report 

(EQR) Data Dictionary. 

SUMMARY: In this notice, the Federal 

Energy Regulatory Commission 

(Commission) proposes to adopt an EQR 

Data Dictionary to define the terms and 

values used in filing EQR data, and 

invites comments on this proposal. 

DATES: Comments on the proposal are 

due June 7, 2007. 

ADDRESSES: You may submit comments 

on the proposal, identified by Docket 

No. RM01–8–006, by one of the 

following methods: 

• Agency Web Site: http:// 

www.ferc.gov. Follow the instructions 

for submitting comments via the eFiling 

link found in the Comment Procedures 

Section of the preamble. 

• Mail: Commenters unable to file 

comments electronically must mail or 

hand deliver an original and 14 copies 

of their comments to the Federal Energy 

Regulatory Commission, Secretary of the 

Commission, 888 First Street, NE., 

Washington, DC 20426. Please refer to 

the Comment Procedures Section of the 

preamble for additional information on 

how to file paper comments. 

FOR FURTHER INFORMATION CONTACT: 

Michelle Veloso (Technical 

Information), Office of Enforcement, 

Federal Energy Regulatory 

Commission, 888 First Street, NE., 

Washington, DC 20426, (202) 502–

8363. 

Gary D. Cohen (Legal Information), 

Office of the General Counsel, Federal 

Energy Regulatory Commission, 888 

First Street, NE., Washington, DC 

20426, (202) 502–8321. 

SUPPLEMENTARY INFORMATION: 

1. The Commission is proposing to 

adopt an Electric Quarterly Report 

(EQR) Data Dictionary that will define 

the terms and values used in filing EQR 

data.1 In this notice, the Commission 

attaches a draft EQR Data Dictionary 

and invites comment on whether this 

document should be adopted or 

modified. 

Background 

2. On April 25, 2002, the Commission 

issued Order No. 2001, a final rule 

establishing revised public utility filing 

requirements.2 This rule revised the 

Commission’s filing requirements to 

require companies subject to the 

Commission’s regulation under section 

205 of the Federal Power Act (public 

utilities) to file quarterly reports that: (1) 

Provide data identifying the utility on 

whose behalf the report is being filed 

(ID Data); (2) summarize pertinent data 

about the utility’s currently effective 

contracts (Contract Data); and (3) 

summarize data about wholesale power 

sales the utility made during the 

reporting period (Transaction Data). The 

requirement to file EQRs replaced the 

requirement to file quarterly transaction 


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3Revised Public Utility Filing Requirements, 99 

FERC ¶ 61,238 (2002); Revised Public Utility Filing 

Requirements, 67 FR 65973 (Oct. 29, 2002), FERC 

Stats. & Regs. ¶ 35,045 (Oct. 21, 2005). 

4Revised Public Utility Filing Requirements, 

Order No. 2001-E, 105 FERC ¶ 61,352 (2003). 

5 Id. at P 8. 

6Posted at http://www.ferc.fed.us/docs-filing/eqr/ 

com-order.asp. 

7Revised Public Utility Filing Requirements, 106 

FERC ¶ 61,281 (2004). 

8Revised Public Utility Filing Requirements for 

Electric Quarterly Reports, Notice of Electric 

Quarterly Reports User’s Group Meeting, Nov. 8, 

2006. 

9See Staff Draft of the EQR Data Dictionary, 

posted on the EQR Users Group and Workshops 

page on FERC.gov at http://www.ferc.gov/docsfiling/eqr/groups-workshops.asp. 

10Revised Public Utility Filing Requirements for 

Electric Quarterly Reports, Notice of Electric 

Quarterly Reports User’s Group Meeting, 71 FR 

69111 (Nov. 29, 2006). 

reports summarizing a utility’s marketbased rate transactions and sales 

agreements that conformed to the 

utility’s tariff. 

3. In Order No. 2001, the Commission 

also adopted a new section in its 

regulations, 18 CFR 35.10b, which 

requires that the EQRs are to be 

prepared in conformance with the 

Commission’s software and guidance 

posted and available from the 

Commission website. This obviates the 

need to revise section 35.10b to 

implement revisions to the software and 

guidance. Since the issuance of Order 

No. 2001, as need has arisen, the 

Commission has issued orders to resolve 

questions raised by EQR users and has 

directed Staff to issue additional 

guidance. For example, in a pair of 

orders issued on May 31 and October 

21, 2002, the Commission provided 

guidance describing how EQR filers 

were to complete several data fields in 

the EQR software.3

4. Likewise, on December 23, 2003, 

the Commission issued Order No. 

2001–E, to resolve some recurring issues 

faced by EQR filers, to help filers better 

understand the requirements of Order 

No. 2001, and to improve the quality 

and consistency of EQR data.4 To this 

end, the Commission: (1) Ordered 

standard formats to be used for certain 

location fields; (2) established an EQR 

Refiling Policy; and (3) streamlined and 

defined allowable data entries in certain 

data fields. The Commission instructed 

Staff to issue filing guidance to address 

these changes.5 This guidance was 

posted on the EQR page of the 

Commission’s website on March 25, 

2004.6 Commission Staff posted 

additional guidance on the Internet at 

the http://www.ferc.gov Web site, and 

several EQR Users Group meetings have 

been held to address the questions of 

EQR filers. 

5. After Order No. 2001–E, the 

Commission recognized that rapid 

change in the electric industry may 

require flexibility in adding or changing 

the entries allowed in restricted fields in 

the EQR. NERC, for example, frequently 

adds and deletes balancing authorities 

(previously ‘‘control areas’’) from its 

Transmission System Information 

Network rolls. In an order issued on 

March 25, 2004, the Commission 

directed Staff to alert EQR users of any 

future changes to allowable entries for 

restricted fields by e-mail, and to post 

these changes on the EQR page of the 

Commission’s Web site.7

6. Since 2004, the Commission has 

performed outreach to the industry to 

determine which current EQR 

definitions are sufficient and 

understandable and which should be 

revised. As relevant here, on November 

8, 2006, the Commission issued a public 

notice announcing that Staff was 

convening a meeting of the EQR Users 

Group to discuss a Staff draft EQR Data 

Dictionary.8 In preparation for that 

meeting, Staff compiled existing 

definitions contained in previous orders 

and Commission issuances.9 In 

addition, Staff suggested revisions and 

refinements to these definitions based 

on more than four years of experience 

reviewing EQR filings, responding to 

questions from EQR filers, and 

discussions with the EQR Users Group. 

Many of the revisions and refinements 

were intended to codify Staff guidance 

provided over the years to clarify 

companies’ EQR filing obligations. Staff 

made its draft EQR Data Dictionary 

available to interested persons before 

the meeting.10

7. Almost 200 people registered to 

attend the November 29, 2006, meeting 

(either in person or via teleconference) 

and many who attended participated in 

the discussion of the issues. Participants 

were invited to file comments on the 

Staff draft EQR Data Dictionary by 

January 12, 2007. Occidental Power 

Services, Inc., Southern California 

Edison Company, and Edison Electric 

Institute (EEI) filed written comments. 

Discussion 

8. To improve the quality of EQR 

filings, the Commission has determined 

that it would be appropriate to issue 

formal definitions for those fields that 

are currently undefined. A common, 

documented basis for the definition of 

the terms and values in the EQR will 

provide the Commission with more 

reliable and understandable information 

related to the contracts and transactions 

reported. Further, a common EQR 

language will create greater regulatory 

certainty for companies responsible for 

filing the EQR. 

9. The proposed EQR Data Dictionary 

compiles all the terms used in the EQR, 

as they have evolved since the issuance 

of Order No. 2001, into an organized 

reference for filers and public use. 

Specifically, the proposed EQR Data 

Dictionary (Attachment A) provides the 

terms and values used to file the EQR. 

It includes terms that were not 

previously defined except through Staff 

guidance. In general, the definitions and 

descriptions are consistent with those 

provided since the issuance of Order 

No. 2001. The underlying structure of 

the EQR will remain unchanged. 

10. The text of this notice and 

Attachment B point out the instances 

where the proposed definitions vary 

from those used in prior Commission 

orders. Attachment B is provided on an 

informational basis only, to aid 

commenters in identifying revisions. 

Comments should only be addressed to 

the proposed EQR Data Dictionary in 

Attachment A. 

11. The proposed EQR Data 

Dictionary revises the definitions 

provided in previous Commission 

orders for the following terms: 

• ID Data: Company Name—

Respondent (Field Number 2); Company 

Name—Seller (Field Number 2); 

Company Name—Agent (Field Number 

2); Company DUNS Number—

Respondent (Field Number 3); Company 

DUNS Number—Seller (Field Number 

3); Company DUNS Number—Agent 

(Field Number 3); Contact Country 

Name (Field Number 10); and Filing 

Quarter (Field Number 13). 

• Contract Data: Seller Company 

Name (Field Number 15); Customer 

Company Name (Field Number 16); 

Customer DUNS Number (Field Number 

17); Contract Affiliate (Field Number 

18); FERC Tariff Reference (Field 

Number 19); Contract Service 

Agreement ID (Field Number 20); 

Contract Execution Date (Field Number 

21); Contract Commencement Date 

(Field Number 22); Contract 

Termination Date (Field Number 23); 

Extension Provision Description (Field 

Number 25); Term Name (Field Number 

27); Product Name (Field Number 31); 

Quantity (Field Number 32); Units 

(Field Number 33); Rate (Field Number 

34); Rate Units (Field Number 38); Point 

of Receipt Balancing Authority (Field 

Number 39); Point of Receipt Specific 

Location (Field Number 40); Point of 

Delivery Balancing Authority (Field 

Number 41); Point of Delivery Specific 

Location (Field Number 42); Begin Date 

(Field Number 43); and End Date (Field 

Number 44). 


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11These definitions are intended to be consistent 

with NERC and the pro forma Open Access 

Transmission Tariff (OATT) definitions and 

Commission precedent. See, e.g., Preventing Undue 

Discrimination and Preference in Transmission 

Service, Order No. 890, 72 FR 12266 (Mar. 15, 

2007), FERC Stats. & Regs. ¶ 31,241 at P 1452–55, 

P 1539 and P 1688–92 (Feb. 16, 2007) (Order No. 

890). However, as explained below, infra P 21, these 

definitions only govern the manner in which these 

items are reported in the EQR. 

12See Market-Based Rates for Wholesale Sales of 

Electric Energy, Capacity and Ancillary Services by 

Public Utilities, notice of proposed rulemaking, 71 

FR 33102 (Jun. 7, 2006), FERC Stats. & Regs. 

¶ 32,602 at P 137 (May 19, 2006). Also, the 

Commission is aware of inconsistencies in these 

definitions with the FERC Form 1 and is in the 

process of reviewing comments in Assessments of 

Information Requirements for FERC Financial 

Forms, notice of inquiry, 72 FR 8316 (Feb. 15, 

2007). 

13As pointed out above, supra note 1, to be 

consistent with NERC terminology, the proposed 

Data Dictionary uses the field name ‘‘PORBA’’

(previously ‘‘PORCA’’ and ‘‘PODBA’’ (previously 

‘‘PODCA’’). 

14See Order No. 890, FERC Stats. & Regs. 

¶ 31,241 at note 499. 

• Transaction Data: Seller Company 

Name (Field Number 47); Customer 

Company Name (Field Number 48); 

Customer DUNS Number (Field Number 

49); FERC Tariff Reference (Field 

Number 50); Contract Service 

Agreement ID (Field Number 51); 

Transaction Begin Date (Field Number 

53); Transaction End Date (Field 

Number 54); Point of Delivery Balancing 

Authority (Field Number 56); Point of 

Delivery Specific Location (Field 

Number 57); Term Name (Field Number 

59); Product Name (Field Number 62); 

Transaction Quantity (Field Number 

62); Price (Field Number 64); Rate Units 

(Field Number 65); Total Transmission 

Charge (Field Number 66); and Total 

Transaction Charge (Field Number 67). 

12. The proposed EQR Data 

Dictionary also adds definitions for 

terms not previously defined by 

Commission order, including: 

• ID Data: Filer Unique Identifier 

(Field Number 1). 

• Contract Data: Contract Unique ID 

(Field Number 14); Class Name (Field 

Number 26); Increment Name (Field 

Number 28); Increment Peaking Name 

(Field Number 29); Product Type Name 

(Field Number 30); and Time Zone 

(Field Number 45). 

• Transaction Data: Transaction 

Unique ID (Field Number 46); Time 

Zone (Field Number 55); Class Name 

(Field Number 58); Increment Name 

(Field Number 60); and Increment 

Peaking Name (Field Number 61). 

13. The proposed EQR Data 

Dictionary makes the following key 

revisions to the existing EQR 

definitions: 

• The definitions of the identifiers 

used at the beginning of each record in 

the comma-delimited import files (Field 

Numbers 1, 14 and 60) have been 

expanded to clarify their function. 

• The definitions of the ID Data fields 

have been expanded to link each of the 

fields to the appropriate filer identified 

in Field Numbers 1 and 2. 

• The definition of ‘‘FERC Tariff 

Reference’’ reported in the Contract Data 

(Field Number 19) and Transaction Data 

(Field Number 50) permits references 

other than the filing company’s own 

FERC tariff where sales occur under 

Commission-approved, cost-based rate 

schedules for certain power pools. 

• The definition of ‘‘Contract Service 

Agreement ID’’ reported in the Contract 

Data (Field Number 20) and in the 

Transaction Data (Field Number 51) 

allows an ‘‘internal identification 

system’’ as opposed to a ‘‘numbering’’

system to allow for the inclusion of nonnumeric characters in the identifiers. 

• The definitions of ‘‘Class Name, FFirm’’ and ‘‘Class Name, NF-Non-Firm’’

reported in the Contract Data (Field 

Number 26) and the Transaction Data 

(Field Number 58) provide two 

definitions, to differentiate between firm 

transmission service and firm power 

sales.11

• The definitions of the allowable 

entries for ‘‘Term Name’’ reported in the 

Contract Data (Field Number 27) and in 

the Transaction Data (Field Number 59) 

are being expanded. While EQR filers 

have indicated a preference that the 

definitions for power sales and 

transmission be differentiated, the 

Commission is striving to create 

consistency for uses of ‘‘long term’’ and 

‘‘short term,’’ across its programs.12

Therefore, we propose to define ‘‘Term 

Name’’ in the same way for both power 

and transmission sales. 

• The definitions of ‘‘Increment 

Peaking Name, OP-Off-Peak’’ and 

‘‘Increment Peaking Name, P-Peak’’

reported in the Contract Data (Field 

Number 29) and the Transaction Data 

(Field Number 61) specify that the 

‘‘relevant NERC region’’ was the ‘‘NERC 

region of the point of delivery.’’

• The definition of ‘‘Increment 

Peaking Name, N/A-Not Applicable’’ in 

the Contract Data (Field Number 29) 

indicates that ‘‘N/A’’ is an acceptable 

entry if the contract does not specify the 

increment peaking period for the sale. 

The definition of ‘‘Increment Peaking 

Name, N/A-Not Applicable’’ in the 

Transaction Data (Field Number 61) 

indicates that ‘‘N/A’’ is an acceptable 

entry only when other available 

increment peaking names do not apply. 

‘‘N/A’’ will not be acceptable for 

products such as ‘‘Energy,’’ ‘‘Booked 

Out Power,’’ ‘‘Capacity,’’ or ‘‘Ancillary 

Services.’’

• The definitions of ‘‘Product Type 

Name, CB-Cost-Based’’ and ‘‘Product 

Type Name, MB-Market-Based’’

reported in the Contract Data (Field 

Number 30) specify ‘‘energy or capacity 

sold’’ under the seller’s FERC-approved 

tariffs. This change allows filers to 

differentiate these product types from 

‘‘Product Type Name, T-Transmission,’’

which applies to cost-based or marketbased transmission-related services. 

• The definition of ‘‘Product Type 

Name, S-Service’’ in the Contract Data 

(Field Number 30) has been deleted to 

remove ambiguity regarding the types of 

products that must be reported. 

• The name and definition of ‘‘Point 

of Receipt Control Area’’ reported in the 

Contract Data (Field Number 39) has 

been revised to ‘‘Point of Receipt 

Balancing Authority’’ in response to 

changes in terminology implemented by 

NERC beginning April 1, 2005. 

• The name and definition of ‘‘Point 

of Delivery Control Area’’ reported in 

the Contract Data (Field Number 41) and 

in the Transaction Data (Field Number 

56) has been revised to ‘‘Point of 

Delivery Balancing Authority’’ in 

response to changes in terminology 

implemented by NERC beginning April 

1, 2005. 

• The continued requirement to fill 

certain Contract Data fields—Contract 

Termination Date (Field Number 23); 

Quantity (Field Number 32); Units 

(Field Number 33); Rate Units (Field 

Number 38); Point of Receipt Balancing 

Authority (PORBA) (Field Number 39); 

Point of Receipt Specific Location 

(PORSL) (Field Number 40); Point of 

Delivery Balancing Authority (PODBA) 

(Field Number 41); Point of Delivery 

Specific Location (PODSL) (Field 

Number 42); Begin Date (Field Number 

43) and End Date (Field Number 44)—

has been clarified to be contractspecific. The EQR may still be filed if 

these fields are left empty, but the 

public utility has the obligation to 

complete the fields if the relevant terms 

are included in the contract.13

• The ‘‘Product Name’’ (Attachment 

A, Appendix A) in the Contract Data 

(Field Number 31), ‘‘Capacity 

Reassignment,’’ has been added to 

address a new EQR reporting 

requirement required by Order No. 

890.14

• The ‘‘Product Names’’ (Attachment 

A, Appendix A) in the Contract Data 

(Field Number 31), ‘‘Regulation & 

Frequency Response,’’ ‘‘Spinning 

Reserve,’’ and ‘‘Supplemental Reserve’’

have been modified to address changes 

in the OATT in Order No. 890. 

• The ‘‘Product Name’’ (Attachment 

A, Appendix A) in the Contract Data 


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15These deals would be reported in Field Number 

29 of Contract Data and in Field Number 61 of 

Transaction Data. 

16 ‘‘5x16’’ (5 days × 16 hours) refers to a peak hour 

weekly deal and ‘‘2 × 24’’ (2 days x 24 hours) refers 

to a weekend deal. 

17See Order No. 890, FERC Stats. & Regs. 

¶ 31,241 at P 1452–55. 

(Field Number 31), ‘‘Exchange 

Agreement,’’ has been revised to 

‘‘Exchange’’ and incorporated into the 

allowable product names in the 

Transaction Data (Field Number 62). 

This change will make it easier to 

identify sales under exchange 

agreements and adjust for their effects 

when reviewing product prices. 

• The ‘‘Product Name’’ (Attachment 

A, Appendix A) in the Contract Data 

(Field Number 31 and Field Number 

62), ‘‘Transmission Owners 

Agreement,’’ has been revised to expand 

the definition beyond agreements with 

ISOs. 

14. Two fields merit specific 

discussion. The Increment Name fields 

(Field Number 28 of the Contract Data 

and Field Number 60 of the Transaction 

Data) are intended to provide insight 

into the duration of the agreement under 

which a sale is being made. To compare 

sales in the EQR appropriately, we must 

be able to understand the duration of 

the underlying transaction that resulted 

in each sale. On a single day in a given 

market, prices for power under terms set 

at the beginning of a month may differ 

from hourly prices determined through 

an RTO or ISO in its real time market. 

The Increment Name fields provide a 

basis to understand price differentiation 

among otherwise similarly situated 

sales. 

15. The proposed EQR Data 

Dictionary includes definitions of 

Increment Names that offer more clarity 

and allow the fields to be automatically 

calculated. These definitions lay out 

specific time periods for each of the 

restricted values. 

16. Deals covering peak periods or offpeak periods (as identified in the 

Increment Peaking Name fields) are 

commonly characterized as daily, rather 

than as hourly transactions, even though 

they last less than 24 hours.15 For this 

reason, the proposed EQR Data 

Dictionary defines ‘‘D-Daily’’

transactions as those under deals that 

last over six and up to and including 

thirty-six hours to ensure that both peak 

and off-peak blocks for a single day are 

included. 

17. Hourly deals, such as sales to 

ISOs, are characterized with terms 

shorter than the daily deals. Under the 

proposed EQR Data Dictionary deals of 

up to, and including, six hours would 

be reported as ‘‘H-Hourly.’’

18. Transactions that cover blocks of 

hours over the course of a week 

(commonly identified in the industry by 

such terms as ‘‘5x16’’ or ‘‘2x24’’) are 

characterized as weekly transactions.16

Sales under deals of over 36 and up to 

and including 168 hours (seven days) 

are defined in the proposed EQR Data 

Dictionary as ‘‘W-Weekly’’ deals. Deals 

over a week (168 hours) and up to and 

including one month would be reported 

as ‘‘M-Monthly.’’ Deals of a year or more 

(including sales where precise terms are 

set in a long-term contract) will be 

reported as ‘‘Y-Yearly.’’ We also propose 

a new ‘‘S-Seasonal’’ value to be used to 

characterize power sales that are made 

for longer than one month but less than 

a year, such as sales for the duration of 

a peak season. 

19. In the Contracts tab, the Increment 

Name field (Field Number 28) has 

descriptive value for those contracts that 

lay out the specific terms (price, 

quantity, and period) of the 

arrangement. Contracts that do not 

contain these specific terms should be 

described using ‘‘N/A.’’

20. Also, in Order No. 890, the 

Commission addressed the issue of what 

constitutes a sufficient level of firmness 

to be eligible for designation as a 

network resource.17 We invite 

comments on whether the definitions of 

Class Names, ‘‘Firm’’ and ‘‘Non-Firm’’

(Field Numbers 26 and 58), need 

revision. 

21. Subject to our review of any 

comments filed in response to this 

notice, the Commission plans to adopt 

the EQR Data Dictionary shown in 

Attachment A to this notice. We expect 

that these definitions would take effect 

the first day of the first new quarter after 

issuance of a Final Order. We caution 

that the definitions we are proposing in 

the EQR Data Dictionary are only 

intended to govern the manner in which 

these items are reported in the EQR and 

are not intended to be precedent in 

other contexts. 

Comment Procedures 

22. The Commission invites interested 

persons to submit comments on the 

matters and issues proposed in this 

notice, including any related matters or 

alternative proposals that commenters 

may wish to discuss. Comments are due 

June 7, 2007. Comments must refer to 

Docket No. RM01–8–006, and must 

include the commenter’s name, the 

organization they represent, if 

applicable, and their address. 

Comments may be filed either in 

electronic or paper format. 

23. Comments may be filed 

electronically via the eFiling link on the 

Commission’s Web site at http:// 

www.ferc.gov. The Commission accepts 

most standard word processing formats 

and commenters may attach additional 

files with supporting information in 

certain other file formats. Commenters 

filing electronically do not need to make 

a paper filing. Commenters that are not 

able to file comments electronically 

must send an original and 14 copies of 

their comments to: Federal Energy 

Regulatory Commission, Secretary of the 

Commission, 888 First Street NE., 

Washington, DC 20426. 

24. All comments will be placed in 

the Commission’s public files and may 

be viewed, printed, or downloaded 

remotely as described in the Document 

Availability section below. Commenters 

on this proposal are not required to 

serve copies of their comments on other 

commenters. 

Document Availability 

25. In addition to publishing the full 

text of this document in the Federal 

Register, the Commission provides all 

interested persons an opportunity to 

view and/or print the contents of this 

document via the Internet through the 

Commission’s Home Page (http:// 

www.ferc.gov) and in the Commission’s 

Public Reference Room during normal 

business hours (8:30 a.m. to 5 p.m. 

Eastern time) at 888 First Street, NE., 

Room 2A, Washington, DC 20426. 

26. From the Commission’s Home 

Page on the Internet, this information is 

available in the eLibrary. The full text 

of this document is available in the 

eLibrary both in PDF and Microsoft 

Word format for viewing, printing, and/ 

or downloading. To access this 

document in eLibrary, type the docket 

number excluding the last three digits of 

this document in the docket number 

field. 

User assistance is available for 

eLibrary and the Commission’s website 

during our normal business hours. For 

assistance contact FERC Online Support 

at FERCOnlineSupport@ferc.gov or tollfree at (866) 208–3676, or for TTY, 

contact (202) 502–8659. 

By direction of the Commission. 

Kimberly D. Bose, 

Secretary. 

Note: The following attachments (A) and 

(B) will not appear in the Code of Federal 

Regulation. 

Attachment A 

Electric Quarterly Report Data 

Dictionary 

Version 1.0 (issued —) 


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EQR DATA DICTIONARY

[ID Data] 

Field No. Field Required Value Definition 

1 ............. Filer Unique Identifier .... ✓ FR1 ................................ (Respondent)—An identifier (i.e., ‘‘FR1’’) used to 

designate a record containing Respondent identification information in a comma-delimited (csv) 

file that is imported into the EQR filing. Only 

one record with the FR1 identifier may be imported into an EQR for a given quarter. 

1 ............. Filer Unique Identifier .... ✓ 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. 

1 ............. Filer Unique Identifier .... ✓ FA1 ................................ (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. 

2 ............. Company Name ............. ✓ Unrestricted text (70 

characters).

(Respondent)—The name of the company taking 

responsibility for complying with the Commission’s regulations related to the EQR. 

2 ............. Company Name ............. ✓ Unrestricted text (70 

characters).

(Seller)—The name of the company that is authorized to make sales as indicated in the company’s FERC tariff(s). This name may be the 

same as the Company Name of the Respondent. 

2 ............. Company Name ............. ✓ Unrestricted text (70 

characters).

(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 ............. Company DUNS Number.For Respondent and 

Seller.

Nine digit number .......... The unique nine digit number assigned by Dun 

and Bradstreet to the company identified in 

Field Number 2. 

4 ............. Contact Name ................ ✓ Unrestricted text (50 

characters).

(Respondent)—Name of the person at the Respondent’s company taking responsibility for 

compliance with the Commission’s EQR regulations. 

4 ............. Contact Name ................ ✓ Unrestricted text (50 

characters).

(Seller)—The name of the contact for the company authorized to make sales as indicated in 

the company’s FERC tariff(s). This name may 

be the same as the Contact Name of the Respondent. 

4 ............. Contact Name ................ ✓ Unrestricted text (50 

characters).

(Agent)—Name of the contact for the Agent, usually the person who prepares the filing. 

5 ............. Contact Title ................... ✓ Unrestricted text (50 

characters).

Title of contact identified in Field Number 4. 

6 ............. Contact Address ............ ✓ Unrestricted text ............. Street address for contact identified in Field Number 4. 

7 ............. Contact City ................... ✓ Unrestricted text (30 

characters).

City for the contact identified in Field Number 4. 

8 ............. Contact State ................. ✓ Unrestricted text (2 characters).Two character state or province abbreviations for 

the contact identified in Field Number 4. 

9 ............. Contact Zip .................... ✓ Unrestricted text (10 

characters).

Zip code for the contact identified in Field Number 

4. 

10 ........... Contact Country Name .. ✓ CA–Canada, MX–Mexico, US–United States, 

UK–United Kingdom.

Country (USA, Canada, Mexico, or United Kingdom) for contact address identified in Field 

Number 4. 

11 ........... Contact Phone ............... ✓ Unrestricted text (20 

characters).

Phone number of contact identified in Field Number 4. 

12 ........... Contact E-Mail ............... ✓ Unrestricted text ............. E-mail address of contact identified in Field Number 4. 

13 ........... Filing Quarter ................. ✓ 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). 


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EQR DATA DICTIONARY—Continued 

[ID Data] 

Field No. Field Required Value Definition 

14 ........... Contract Unique ID ........ ✓ An integer proceeded by 

the letter ‘‘C’’ (only 

used when importing 

contract data).

An identifier beginning with the letter ‘‘C’’ and followed by a number (e.g., ‘‘C1’’, ‘‘C2’’) used to 

designate a record containing contract information in a comma-delimited (csv) file that is imported into the EQR filing. One record for each 

contract product may be imported into an EQR 

for a given quarter. 

15 ........... Seller Company Name .. ✓ Unrestricted text (70 

characters).

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). 

16 ........... Customer Company 

Name.

✓ Unrestricted text (70 

characters).

The name of the counterparty to the contract. 

17 ........... Customer DUNS Number.✓ Nine digit number .......... The unique nine digit number assigned by Dun 

and Bradstreet to the company identified in 

Field Number 16. 

18 ........... Contract Affiliate ............ ✓ Y (Yes) N (No) ............... The customer is an affiliate if it controls, is controlled by or is under common control with the 

seller. This includes a division that operates as 

a functional unit. A customer of a seller who is 

an Exempt Wholesale Generator may be defined as an affiliate under the Public Utility 

Holding Company Act and the FPA. 

19 ........... FERC Tariff Reference .. ✓ Unrestricted text (60 

characters).

The FERC tariff reference cites the document that 

specifies the terms and conditions under which 

a Seller is authorized to make transmission 

sales or power sales at cost-based rates or at 

market-based rates. If the sales are marketbased, the tariff that is specified in the FERC 

order granting the Seller Market Based Rate 

Authority must be listed. 

20 ........... Contract Service Agreement ID.✓ Unrestricted text (30 

characters).

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. 

21 ........... Contract Execution Date ✓ YYYYMMDD .................. The date the contract was signed. If the parties 

signed on different dates, or there are contract 

amendments, use the most recent date signed. 

22 ........... Contract Commencement Date.✓ YYYYMMDD .................. The date the contract was effective. If it is not 

specified in the contract, the first date of service 

under the contract. 

23 ........... Contract Termination 

Date.

If specified in the contract.YYYYMMDD .................. The date that the contract expires. 

24 ........... Actual Termination Date If contract terminated ..... YYYYMMDD .................. The date the contract actually terminates. 

25 ........... Extension Provision Description.✓ Unrestricted text ............. Description of terms that provide for the continuation of the contract. 

26 ........... Class Name ................... ✓ ........................................ See definitions of each class name below. 

26 ........... Class Name ................... ✓ F—Firm .......................... For transmission sales, service or product that always has priority over non-firm service. For 

power sales, service or product that is not interruptible for economic reasons. 

26 ........... Class Name ................... ✓ NF—Non-firm ................. For transmission sales, 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. An energy 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. 

26 ........... Class Name ................... ✓ UP—Unit Power Sale .... Designates a dedicated sale of energy and capacity from one or more than one generation 

unit(s). 

26 ........... Class Name ................... ✓ N/A—Not Applicable ...... To be used only when the other available Class 

Names do not apply. 


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EQR DATA DICTIONARY—Continued 

[ID Data] 

Field No. Field Required Value Definition 

27 ........... Term Name .................... ✓ LT—Long Term, ST—

Short Term, N/A—Not 

Applicable.

Contracts with durations of one year or greater 

are long-term. Contracts with shorter durations 

are short-term. 

28 ........... Increment Name ............ ✓ ........................................ See definitions for each increment below. 

28 ........... Increment Name ............ ✓ H—Hourly ...................... Terms of the contract (if specifically noted in the 

contract) set for up to 6 consecutive hours (= 6 

consecutive hours). 

28 ........... Increment Name ............ ✓ D—Daily ......................... Terms of the contract (if specifically noted in the 

contract) set for more than 6 and up to 36 consecutive hours (≤6 and = 36 consecutive 

hours). 

28 ........... Increment Name ............ ✓ W—Weekly .................... Terms of the contract (if specifically noted in the 

contract) set for over 36 consecutive hours and 

up to 168 consecutive hours (≤36 and = 168 

consecutive hours). 

28 ........... Increment Name ............ ✓ M—Monthly .................... Terms of the contract (if specifically noted in the 

contract) set for more than 168 consecutive 

hours up to one month (>168 consecutive 

hours and ≤ 1 month). 

28 ........... Increment Name ............ ✓ Y—Yearly ....................... Terms of the contract (if specifically noted in the 

contract) set for one year or more (≥1 year). 

28 ........... Increment Name ............ ✓ S—Seasonal .................. Terms of the contract (if specifically noted in the 

contract) set for greater than one month and 

less than 365 consecutive days (> 1 month and 

< 1 year). 

28 ........... Increment Name ............ ✓ N/A—Not Applicable ...... Terms of the contract do not specify an increment. 

29 ........... Increment Peaking 

Name.

✓ ........................................ See definitions for each increment peaking name 

below. 

29 ........... Increment Peaking 

Name.

✓ FP—Full Period ............. The product described may be sold during all 

hours under the contract. 

29 ........... Increment Peaking 

Name.

✓ OP—Off-Peak ................ The product described may be sold only during 

those hours designated as off-peak in the 

NERC region of the point of delivery. 

29 ........... Increment Peaking 

Name.

✓ P—Peak ......................... The product described may be sold only during 

those hours designated as on-peak in the 

NERC region of the point of delivery. 

29 ........... Increment Peaking 

Name.

✓ N/A—Not Applicable ...... To be used only when the increment peaking 

name is not specified in the contract. 

30 ........... Product Type Name ....... ✓ ........................................ See definitions for each product type below. 

30 ........... Product Type Name ....... ✓ CB—Cost Based ............ Energy or capacity sold under a FERC-approved 

cost-based rate tariff. 

30 ........... Product Type Name ....... ✓ MB—Market Based ........ Energy sold under the seller’s FERC-approved 

market-based rate tariff. 

30 ........... Product Type Name ....... ✓ T—Transmission ............ The product is sold under a FERC-approved 

transmission tariff. 

30 ........... Product Type Name ....... ✓ Other .............................. The product cannot be characterized by the other 

product type names. 

31 ........... Product Name ................ ✓ See Product Name 

Table, Appendix A..

Description of product being offered. 

32 ........... Quantity .......................... If specified in the contract.Number with up to 4 

decimals.

Quantity for the contract product identified. 

33 ........... Units ............................... If specified in the contract.See Units Table, Appendix E.Measure stated in the contract for the product 

sold. 

34 ........... Rate ............................... One of four rate fields 

(34, 35, 36, or 37) 

must be included.

Number with up to 4 

decimals.

The charge for the product per unit as stated in 

the contract. 

35 ........... Rate Minimum ................ One of four rate fields 

(34, 35, 36, or 37) 

must be included.

Number with up to 4 

decimals.

Minimum rate to be charged per the contract, if a 

range is specified. 

36 ........... Rate Maximum ............... One of four rate fields 

(34, 35, 36, or 37) 

must be included.

Number with up to 4 

decimals.

Maximum rate to be charged per the contract, if a 

range is specified. 

37 ........... Rate Description ............ One of four rate fields 

(34, 35, 36, or 37) 

must be included.

Unrestricted text ............. Text description of rate. May reference FERC tariff, or, if a discounted or negotiated rate, include 

algorithm. 

38 ........... Rate Units ...................... If specified in the contract.See Rate Units Table, 

Appendix F.

Measure stated in the contract for the product 

sold. 


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EQR DATA DICTIONARY—Continued 

[ID Data] 

Field No. Field Required Value Definition 

39 ........... Point of Receipt Balancing Authority 

(PORBA).

If specified in the contract.See Balancing Authority 

Table, Appendix B.

The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation 

used in OASIS applications or ‘‘Hub’’ if point of 

receipt is at a restricted trading hub. 

40 ........... Point of Receipt Specific 

Location (PORSL).

If specified in the contract.Unrestricted text (50 

characters). If ‘‘HUB’’

is selected for 

PORCA, see Hub 

Table, Appendix C.

The specific location at which the product is received if designated in the contract. If receipt 

occurs at a trading hub, a standardized hub 

name must be used. 

41 ........... Point of Delivery Balancing Authority(PODBA).If specified in the contract.See Balancing Authority 

Table, Appendix B.

The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation 

used in OASIS applications or ‘‘Hub’’ if point of 

receipt is at a restricted trading hub. 

42 ........... Point of Delivery Specific 

Location (PODSL).

If specified in the contract.Unrestricted text (50 

characters). If ‘‘HUB’’

is selected for 

PODCA, see Hub 

Table, Appendix C.

The specific location at which the product is delivered if designated in the contract. If receipt occurs at a trading hub, a standardized hub name 

must be used. 

43 ........... Begin Date ..................... If specified in the contract.YYYYMMDDHHMM ....... First date for the sale of the product at the rate 

specified. 

44 ........... End Date ........................ If specified in the contract.YYYYMMDDHHMM ....... Last date for the sale of the product at the rate 

specified. 

45 ........... Time Zone ...................... ✓ See Time Zone Table, 

Appendix D.

The time zone in which the sales will be made 

under the contract. 

EQR DATA DICTIONARY

[Transaction Data] 

Field No. Field Required Value Definition 

46 ............. Transaction Unique ID ......... ✓ An integer proceeded by the 

letter ‘‘T’’ (only used when 

importing transaction 

data).

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. 

47 ............. Seller Company Name ........ ✓ Unrestricted text (70 Characters).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). 

48 ............. Customer Company Name .. ✓ Unrestricted text (70 Characters).The name of the counterparty to the contract. 

49 ............. Customer DUNS Number .... ✓ Nine digit number ................ The unique nine digit number assigned by Dun and 

Bradstreet to the counterparty to the contract. 

50 ............. FERC Tariff Reference ........ ✓ Unrestricted text (60 Characters).The FERC tariff reference cites the document that specifies the terms and conditions under which a Seller is 

authorized to make transmission sales or power sales 

at cost-based rates or at market-based rates. If the 

sales are market-based, the tariff that is specified in 

the FERC order granting the Seller Market Based Rate 

Authority must be listed. 

51 ............. Contract Service Agreement 

ID.

✓ Unrestricted text (30 Characters).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. 

52 ............. Transaction Unique Identifier ✓ Unrestricted text (24 Characters).Unique reference number assigned by the seller for each 

transaction. 

53 ............. Transaction Begin Date ....... ✓ YYYYMMDDHHMM (csv import).First date and time the product is sold during the quarter 

at the specified price. 

MMDDYYYYHHMM (manual 

entry).

54 ............. Transaction End Date .......... ✓ YYYYMMDDHHMM (csv import).Last date and time the product is sold during the quarter 

at the specified price. 


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EQR DATA DICTIONARY—Continued 

[Transaction Data] 

Field No. Field Required Value Definition 

MMDDYYYYHHMM (manual 

entry).

55 ............. Time Zone ........................... ✓ See Time Zone Table, Appendix D.The time zone in which the sales will be made under the 

contract. 

56 ............. Point of Delivery Balancing 

Authority (PODBA).

✓ See Balancing Authority 

Table, Appendix B.

The registered NERC Balancing Authority (formerly 

called NERC Control Area) abbreviation used in 

OASIS applications. 

57 ............. Point of Delivery Specific 

Location (PODSL).

✓ Unrestricted text (50 characters). If ‘‘HUB’’ is selected for PODBA, see 

Hub Table, Appendix C.

The specific location at which the product is delivered. If 

receipt occurs at a trading hub, a standardized hub 

name must be used. 

58 ............. Class Name ......................... ✓ .............................................. See class name definitions below. 

58 ............. Class Name ......................... ✓ F—Firm ................................ For transmission sales, service or product that always 

has priority over non-firm service. For power sales, 

service or product that is not interruptible for economic 

reasons. 

58 ............. Class Name ......................... ✓ NF—Non-firm ....................... For transmission sales, 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 transmission service. An energy sale for which 

delivery or receipt of the energy may be interrupted for 

any reason or no reason, without liability on the part of 

either the buyer or seller. 

58 ............. Class Name ......................... ✓ UP—Unit Power Sale .......... Designates a dedicated sale of energy and capacity from 

one or more than one generation unit(s). 

58 ............. Class Name ......................... ✓ BA—Billing Adjustment ........ Incremental positive or negative material change to previous EQR totals. 

58 ............. Class Name ......................... ✓ N/A—Not Applicable ............ To be used only when the other available class names 

do not apply. 

59 ............. Term Name .......................... ✓ LT—Long Term, ST—Short 

Term, N/A—Not Applicable.

Power sales transactions with durations of one year or 

greater are long-term. Transactions with shorter durations are short-term. 

60 ............. Increment Name .................. ✓ .............................................. See increment name definitions below. 

60 ............. Increment Name .................. ✓ H—Hourly ............................ Terms of the particular sale set for up to 6 consecutive 

hours (≤ 6 consecutive hours) Includes LMP based 

sales in ISO/RTO markets. 

60 ............. Increment Name .................. ✓ D—Daily ............................... Terms of the particular sale set for more than 6 and up 

to 36 consecutive hours (> 6 and ≤ 36 consecutive 

hours) Includes sales over a peak or off-peak block 

during a single day. 

60 ............. Increment Name .................. ✓ W—Weekly .......................... Terms of the particular sale set for over 36 consecutive 

hours and up to 168 consecutive hours (> 36 and ≤ 168 

consecutive hours). Includes sales for a full week and 

sales for peak and off-peak blocks over a particular 

week. 

60 ............. Increment Name .................. ✓ M—Monthly .......................... Terms of the particular sale set for more than 168 consecutive hours up to one month (> 168 consecutive 

hours and ≤ 1 month). Includes sales for full month or 

multi-week sales during a given month. 

60 ............. Increment Name .................. ✓ S—Seasonal ........................ Terms of the specific sales set for greater than one 

month and less than 365 consecutive days (> 1 month 

and < 1 year). 

60 ............. Increment Name .................. ✓ Y—Yearly ............................. Terms of the particular sale set for one year or more (≥ 1 

year). Includes all long-term contracts with defined 

pricing terms (fixed-price, formula, or index). 

60 ............. Increment Name .................. ✓ N/A—Not Applicable ............ To be used only when other available increment names 

do not apply. 

61 ............. Increment Peaking Name .... ✓ See definitions for increment 

peaking below.

61 ............. Increment Peaking Name .... ✓ FP—Full Period ................... The product described may be sold during all hours 

under the contract. 

61 ............. Increment Peaking Name .... ✓ OP—Off-Peak ...................... The product described may be sold only during those 

hours designated as off-peak in the NERC region of 

the point of delivery. 

61 ............. Increment Peaking Name .... ✓ P—Peak ............................... The product described may be sold only during those 

hours designated as on-peak in the NERC region of 

the point of delivery. 

61 ............. Increment Peaking Name .... ✓ N/A—Not Applicable ............ To be used only when the other available increment 

peaking names do not apply. 


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26100 Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 

EQR DATA DICTIONARY—Continued 

[Transaction Data] 

Field No. Field Required Value Definition 

62 ............. Product Name ...................... ✓ See Product Names Table, 

Appendix A.

Description of product being offered. 

63 ............. Transaction Quantity ........... ✓ Number with up to 4 decimals.The quantity of the product in this transaction. 

64 ............. Price ..................................... ✓ Number with up to 6 decimals.Price charged for the product per unit. 

65 ............. Rate Units ............................ ✓ See Rate Units Table, Appendix F.Measure appropriate to the price of the product sold. 

66 ............. Total Transmission Charge ✓ Number with up to 2 decimals.Payments received for transmission services when explicitly identified. 

67 ............. Total Transaction Charge .... ✓ Number with up to 2 decimals.Transaction Quantity (Field 63) times Price (Field 64) 

plus Total Transmission Charge (Field 66). 

EQR DATA DICTIONARY

[Appendix A. Product Names] 

Product name Contract 

product 

Transaction 

product Definition 

BLACK START SERVICE ................. ✓ ✓ Service available after a system-wide blackout where a generator participates in system restoration activities without the availability of an outside electric supply (Ancillary Service). 

BOOKED OUT POWER ................... ...................... ✓ Energy or capacity contractually committed bilaterally for delivery but not 

actually delivered due to some offsetting or countervailing trade (Transaction only). 

CAPACITY ........................................ ✓ ✓ A quantity of demand that is charged on a $/KW or $/MW basis. 

CAPACITY REASSIGNMENT .......... ✓ ...................... An agreement under which a transmission customer sells, assigns or 

transfers all or portion of its rights to an eligible customer. 

CUSTOMER CHARGE ..................... ✓ ✓ Fixed contractual charges assessed on a per customer basis that could 

include billing service. 

DIRECT ASSIGNMENT FACILITIES 

CHARGE.

✓ ...................... Charges for facilities or portions of facilities that are constructed or used 

for the sole use/benefit of a particular customer. 

EMERGENCY ENERGY ................... ✓ ...................... Contractual provisions to supply energy or capacity to another entity during critical situations. 

ENERGY ........................................... ✓ ✓ A quantity of electricity that is sold or transmitted over a period of time. 

ENERGY IMBALANCE ..................... ✓ ✓ Service provided when a difference occurs between the scheduled and 

the actual delivery of energy to a load obligation. 

EXCHANGE ...................................... ✓ ✓ (Previously ‘‘Exchange Agreement’’). Transaction whereby the receiver 

accepts delivery of energy for a supplier’s account and returns energy 

later at times, rates, and in amounts as mutually agreed. 

FUEL CHARGE ................................. ✓ ✓ Charge based on the cost or amount of fuel used for generation. 

GRANDFATHERED BUNDLED ........ ✓ ✓ Services provided for bundled transmission, ancillary services and energy 

under contracts effective prior to Order No. 888’s OATTs. 

INTERCONNECTION AGREEMENT ✓ ...................... 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 .......... ✓ ...................... Agreement to participate and be subject to rules of a system operator. 

MUST RUN AGREEMENT ............... ✓ ...................... An agreement that requires a unit to run. 

NEGOTIATED-RATE TRANSMISSION.✓ ✓ Transmission performed under a negotiated rate contract (applies only to 

merchant transmission companies). 

NETWORK ........................................ ✓ ...................... Transmission service under contract providing network service. 

NETWORK OPERATING AGREEMENT.✓ ...................... 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 .............................................. ✓ ✓ Product name not otherwise included. 

POINT-TO-POINT AGREEMENT ..... ✓ ...................... Transmission service under contract between specified Points of Receipt 

and Delivery. 

REACTIVE SUPPLY & VOLTAGE 

CONTROL.

✓ ✓ Production or absorption of reactive power to maintain voltage levels on 

transmission systems (Ancillary Service). 

REAL POWER TRANSMISSION 

LOSS.

✓ ✓≤ The loss of energy, resulting from transporting power over a transmission 

system. 

REGULATION & FREQUENCY RESPONSE.✓ ✓ Service providing for continuous balancing of resources (generation and 

interchange) with load, and for maintaining scheduled interconnection 

frequency by committing on-line generation where output is raised or 

lowered and by other non-generation resources capable of providing 

this service as necessary to follow the moment-by-moment changes in 

load (Ancillary Service). 


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Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 26101 

EQR DATA DICTIONARY—Continued 

[Appendix A. Product Names] 

Product name Contract 

product 

Transaction 

product Definition 

REQUIREMENTS SERVICE ............ ✓ ✓ Firm, load-following power supply necessary to serve a specified share of 

customer’s aggregate load during the term of the agreement. Requirements service may include some or all of the energy, capacity and ancillary service products. (If the components of the requirements service 

are priced separately, they should be reported separately in the transactions tab.) 

SCHEDULE SYSTEM CONTROL & 

DISPATCH.

✓ ✓ Scheduling, confirming and implementing an interchange schedule with 

other Balancing Authorities, including intermediary Balancing Authorities providing transmission service, and ensuring operational security 

during the interchange transaction (Ancillary Service). 

SPINNING RESERVE ....................... ✓ ✓ 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). 

SUPPLEMENTAL RESERVE ........... ✓ ✓ Service needed to serve load in the event of a system contingency, available with greater delay than SPINNING RESERVE. This service may 

be provided by generating units that are on-line but unloaded, by 

quick-start generation, or by interruptible load or other non-generation 

resources capable of providing this service (Ancillary Service). 

SYSTEM OPERATING AGREEMENTS.✓ ✓ 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 ........................... ✓ ✓ 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.✓ ...................... The agreement that establishes the terms and conditions under which a 

transmission owner transfers operational control over designated transmission facilities. 

UPLIFT .............................................. ✓ ✓ A make-whole payment by an RTO/ISO to a utility. 

EQR DATA DICTIONARY

[Appendix B. Balancing Authority] 

Balancing authority Abbreviation 

AESC, LLC—Wheatland CIN ........................................................................................................................................................... AEWC 

Alabama Electric Cooperative, Inc. .................................................................................................................................................. AEC 

Alberta Electric System Operator ..................................................................................................................................................... AESO 

Alliant Energy Corporate Services, LLC—East ................................................................................................................................ ALTE 

Alliant Energy Corporate Services, LLC—West ............................................................................................................................... ALTW 

Ameren Transmission ....................................................................................................................................................................... AMRN 

Ameren Transmission. Illinois ........................................................................................................................................................... AMIL 

Ameren Transmission. Missouri ....................................................................................................................................................... AMMO 

American Transmission Systems, Inc. ............................................................................................................................................. FE 

Aquila Networks—Kansas ................................................................................................................................................................ WPEK 

Aquila Networks—Missouri Public Service ....................................................................................................................................... MPS 

Aquila Networks—West Plains Dispatch .......................................................................................................................................... WPEC 

Arizona Public Service Company ..................................................................................................................................................... AZPS 

Associated Electric Cooperative, Inc. ............................................................................................................................................... AECI 

Avista Corp. ...................................................................................................................................................................................... AVA 

Batesville Balancing Authority .......................................................................................................................................................... BBA 

Big Rivers Electric Corp. .................................................................................................................................................................. BREC 

Board of Public Utilities .................................................................................................................................................................... KACY 

Bonneville Power Administration Transmission ............................................................................................................................... BPAT 

California Independent System Operator ......................................................................................................................................... CISO 

Carolina Power & Light Company—CPLW ...................................................................................................................................... CPLW 

Carolina Power and Light Company—East ...................................................................................................................................... CPLE 

Central and Southwest ..................................................................................................................................................................... CSWS 

Central Illinois Light Co .................................................................................................................................................................... CILC 

Chelan County PUD ......................................................................................................................................................................... CHPD 

Cinergy Corporation .......................................................................................................................................................................... CIN 

City of Homestead ............................................................................................................................................................................ HST 

City of Independence P&L Dept. ...................................................................................................................................................... INDN 

City of Tallahassee ........................................................................................................................................................................... TAL 

City Water Light & Power ................................................................................................................................................................. CWLP 

Cleco Power LLC .............................................................................................................................................................................. CLEC 

Columbia Water & Light ................................................................................................................................................................... CWLD 

Comision Federal de Electricidad ..................................................................................................................................................... CFE 

Constellation Energy Control and Dispatch—Arkansas ................................................................................................................... PUPP


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EQR DATA DICTIONARY—Continued 

[Appendix B. Balancing Authority] 

Balancing authority Abbreviation 

Constellation Energy Control and Dispatch—City of Benton, AR .................................................................................................... BUBA 

Constellation Energy Control and Dispatch—City of Ruston, LA .................................................................................................... DERS 

Constellation Energy Control and Dispatch—Conway, Arkansas .................................................................................................... CNWY 

Constellation Energy Control and Dispatch—Gila River .................................................................................................................. GRMA 

Constellation Energy Control and Dispatch—Harquehala ............................................................................................................... HGMA 

Constellation Energy Control and Dispatch—North Little Rock, AK ................................................................................................ DENL 

Constellation Energy Control and Dispatch—West Memphis, Arkansas ......................................................................................... WMUC 

Dairyland Power Cooperative ........................................................................................................................................................... DPC 

DECA, LLC—Arlington Valley .......................................................................................................................................................... DEAA 

Duke Energy Corporation ................................................................................................................................................................. DUK 

East Kentucky Power Cooperative, Inc. ........................................................................................................................................... EKPC 

El Paso Electric ................................................................................................................................................................................ EPE 

Electric Energy, Inc. .......................................................................................................................................................................... EEI 

Empire District Electric Co., The ...................................................................................................................................................... EDE 

Entergy .............................................................................................................................................................................................. EES 

ERCOT ISO ...................................................................................................................................................................................... ERCO 

Florida Municipal Power Pool ........................................................................................................................................................... FMPP 

Florida Power & Light ....................................................................................................................................................................... FPL 

Florida Power Corporation ................................................................................................................................................................ FPC 

Gainesville Regional Utilities ............................................................................................................................................................ GVL 

Georgia System Operations Corporation ......................................................................................................................................... GSOC 

Georgia Transmission Corporation ................................................................................................................................................... GTC 

Grand River Dam Authority .............................................................................................................................................................. GRDA 

Grant County PUD No. 2 .................................................................................................................................................................. GCPD 

Great River Energy ........................................................................................................................................................................... GRE 

Great River Energy ........................................................................................................................................................................... GREC 

Great River Energy ........................................................................................................................................................................... GREN 

Great River Energy ........................................................................................................................................................................... GRES 

GridAmerica ...................................................................................................................................................................................... GA 

Hoosier Energy ................................................................................................................................................................................. HE 

Hydro-Quebec, TransEnergie ........................................................................................................................................................... HQT 

Idaho Power Company ..................................................................................................................................................................... IPCO 

Illinois Power Co. .............................................................................................................................................................................. IP 

Illinois Power Co. .............................................................................................................................................................................. IPRV 

Imperial Irrigation District .................................................................................................................................................................. IID 

Indianapolis Power & Light Company .............................................................................................................................................. IPL 

ISO New England Inc. ...................................................................................................................................................................... ISNE 

JEA ................................................................................................................................................................................................... JEA 

Kansas City Power & Light, Co ........................................................................................................................................................ KCPL 

Lafayette Utilities System ................................................................................................................................................................. LAFA 

LG&E Energy Transmission Services .............................................................................................................................................. LGEE 

Lincoln Electric System .................................................................................................................................................................... LES 

Los Angeles Department of Water and Power ................................................................................................................................ LDWP 

Louisiana Energy & Power Authority ................................................................................................................................................ LEPA 

Louisiana Generating, LLC ............................................................................................................................................................... LAGN 

Madison Gas and Electric Company ................................................................................................................................................ MGE 

MHEB, Transmission Services ......................................................................................................................................................... MHEB 

Michigan Electric Coordinated System ............................................................................................................................................. MECS 

Michigan Electric Coordinated System—CONS ............................................................................................................................... CONS 

Michigan Electric Coordinated System—DECO ............................................................................................................................... DECO 

MidAmerican Energy Company ........................................................................................................................................................ MEC 

Midwest ISO ..................................................................................................................................................................................... MISO 

Minnesota Power, Inc. ...................................................................................................................................................................... MP 

Montana-Dakota Utilities Co. ............................................................................................................................................................ MDU 

Muscatine Power and Water ............................................................................................................................................................ MPW 

Nebraska Public Power District ........................................................................................................................................................ NPPD 

Nevada Power Company .................................................................................................................................................................. NEVP 

New Brunswick Power Corporation .................................................................................................................................................. NBPC 

New Horizons Electric Cooperative .................................................................................................................................................. NHC1 

New York Independent System Operator ........................................................................................................................................ NYIS 

North American Electric Reliability Council ...................................................................................................................................... TEST 

Northern Indiana Public Service Company ...................................................................................................................................... NIPS 

Northern States Power Company ..................................................................................................................................................... NSP 

NorthWestern Energy ....................................................................................................................................................................... NWMT 

Ohio Valley Electric Corporation ...................................................................................................................................................... OVEC 

Oklahoma Gas and Electric .............................................................................................................................................................. OKGE 

Ontario—Independent Electricity Market Operator .......................................................................................................................... IMO 

OPPD CA/TP .................................................................................................................................................................................... OPPD 

Otter Tail Power Company ............................................................................................................................................................... OTP 

P.U.D. No. 1 of Douglas County ...................................................................................................................................................... DOPD 

PacifiCorp—East ............................................................................................................................................................................... PACE 


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EQR DATA DICTIONARY—Continued 

[Appendix B. Balancing Authority] 

Balancing authority Abbreviation 

PacifiCorp—West .............................................................................................................................................................................. PACW 

PJM Interconnection ......................................................................................................................................................................... PJM 

Portland General Electric .................................................................................................................................................................. PGE 

Public Service Company of Colorado .............................................................................................................................................. PSCO 

Public Service Company of New Mexico ......................................................................................................................................... PNM 

Puget Sound Energy Transmission .................................................................................................................................................. PSEI 

Reedy Creek Improvement District .................................................................................................................................................. RC 

Sacramento Municipal Utility District ................................................................................................................................................ SMUD 

Salt River Project .............................................................................................................................................................................. SRP 

Santee Cooper .................................................................................................................................................................................. SC 

SaskPower Grid Control Centre ....................................................................................................................................................... SPC 

Seattle City Light .............................................................................................................................................................................. SCL 

Seminole Electric Cooperative ......................................................................................................................................................... SEC 

Sierra Pacific Power Co.—Transmission ......................................................................................................................................... SPPC 

South Carolina Electric & Gas Company ......................................................................................................................................... SCEG 

South Mississippi Electric Power Association .................................................................................................................................. SME 

South Mississippi Electric Power Association .................................................................................................................................. SMEE 

Southeastern Power Administration—Hartwell ................................................................................................................................. SEHA 

Southeastern Power Administration—Russell .................................................................................................................................. SERU 

Southeastern Power Administration—Thurmond ............................................................................................................................. SETH 

Southern Company Services, Inc. .................................................................................................................................................... SOCO 

Southern Illinois Power Cooperative ................................................................................................................................................ SIPC 

Southern Indiana Gas & Electric Co. ............................................................................................................................................... SIGE 

Southern Minnesota Municipal Power Agency ................................................................................................................................. SMP 

Southwest Power Pool ..................................................................................................................................................................... SWPP 

Southwestern Power Administration ................................................................................................................................................. SPA 

Southwestern Public Service Company ........................................................................................................................................... SPS 

Sunflower Electric Power Corporation .............................................................................................................................................. SECI 

Tacoma Power .................................................................................................................................................................................. TPWR 

Tampa Electric Company ................................................................................................................................................................. TEC 

Tennessee Valley Authority ESO ..................................................................................................................................................... TVA 

Trading Hub ...................................................................................................................................................................................... HUB 

TRANSLink Management Company ................................................................................................................................................ TLKN 

Tucson Electric Power Company ..................................................................................................................................................... TEPC 

Turlock Irrigation District ................................................................................................................................................................... TIDC 

Upper Peninsula Power Co. ............................................................................................................................................................. UPPC 

Utilities Commission, City of New Smyrna Beach ........................................................................................................................... NSB 

Westar Energy—MoPEP Cities ........................................................................................................................................................ MOWR 

Western Area Power Administration—Colorado-Missouri ................................................................................................................ WACM 

Western Area Power Administration—Lower Colorado ................................................................................................................... WALC 

Western Area Power Administration—Upper Great Plains East ..................................................................................................... WAUE 

Western Area Power Administration—Upper Great Plains West .................................................................................................... WAUW

Western Farmers Electric Cooperative ............................................................................................................................................ WFEC 

Western Resources dba Westar Energy .......................................................................................................................................... WR 

Wisconsin Energy Corporation ......................................................................................................................................................... WEC 

Wisconsin Public Service Corporation ............................................................................................................................................. WPS 

Yadkin, Inc. ....................................................................................................................................................................................... YAD 

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. 

AEP (into) ........................................ The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery 

into the AEP balancing authority. 

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’’) nodes defined by the Midwest Independent Transmission System Operator, Inc., as Cinergy Hub (MISO). 

Comed (into) ................................... The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery 

into the Commonwealth Edison balancing authority. 

Entergy (into) .................................. The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery 

into the Entergy balancing authority. 


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EQR DATA DICTIONARY—Continued 

[Appendix C. Hub] 

HUB Definition 

FE Hub ............................................ The aggregated Elemental Pricing nodes (‘‘Epnodes’’) nodes 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’’) nodes 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’’) nodes 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’’) nodes 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. 

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. 

EQR DATA DICTIONARY—Continued 

[Appendix E. Units] 

Units Definition 

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. 

EQR DATA DICTIONARY—Continued 

[Appendix F. Rate Units] 

Rate units Definition 

$/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. 


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Attachment B 

Explanation and Comparison of 

Revisions to Prior Commission Orders 

Contained in the Proposed EQR Data 

Dictionary Definitions 

ID DATA 

Respondent Data 

Field Number 1: Filer Unique Identifier 

Current Definition: None 

Proposed Definition: FR (Filing 

Respondent)—An identifier (i.e., ‘‘FR1’’) 

used to designate a record containing 

Respondent identification information 

in a comma-delimited (csv) file that is 

imported into the EQR filing. Only one 

record with the FR1 identifier may be 

imported into an EQR for a given 

quarter. 

Field Number 2: Company Name 

Current Definition: Name of company 

(for consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report). 

Proposed Definition: The name of the 

company taking responsibility for 

complying with the Commission’s 

regulations related to the EQR. 

Field Number 3: Company Duns 

Number 

Current Definition: DUNS number for 

company unique identification. 

Proposed Definition: The unique nine 

digit number assigned by Dun and 

Bradstreet to the company identified in 

Field Number 2. 

Field Number 4: Contact Name 

Current Definition: Name of contact(s) 

for the filing. 

Proposed Definition: Name of the 

person at the Respondent’s company 

taking responsibility for compliance 

with the Commission’s EQR regulations. 

Field Number 5: Contact Title 

Current Definition: Title of contact. 

Proposed Definition: Title of contact 

identified in Field Number 4. 

Field Number 6: Contact Address 

Current Definition: Street address for 

contact. 

Proposed Definition: Street address 

for contact identified in Field Number 4. 

Field Number 7: Contact City 

Current Definition: Contact city. 

Proposed Definition: Contact city for 

the contact identified in Field Number 

4. 

Field Number 8: Contact State 

Current Definition: Two character 

state or province abbreviation. 

Proposed Definition: Two character 

state or province abbreviations for the 

contact identified in Field Number 4. 

Field Number 9: Contact Zip 

Current Definition: Contact zip code. 

Proposed Definition: Zip code for the 

contact identified in Field Number 4. 

Field Number 10: Contact Country 

Name 

Current Definition: Country (USA, 

Canada, Mexico, or United Kingdom) for 

contact address for the company 

identified in Field Number 2. 

Proposed Definition: Contact address 

for the contact identified in Field 

Number 4. 

Field Number 11: Contact Phone 

Current Definition: Phone number of 

contact. 

Proposed Definition: Phone number of 

contact identified in Field Number 4. 

Field Number 12: Contact Email 

Current Definition: E-mail address of 

contact. 

Proposed Definition: E-mail address 

of contact identified in Field Number 4. 

Field Number 13: Filing Quarter 

Current Definition: The period for 

which the Electric Quarterly Report is 

being submitted. 

Proposed Definition: 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) 

Seller Data 

Field Number 1: Filer Unique Identifier 

Current Definition: None 

Proposed Definition: FS (Filing 

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. 

Field Number 2: Company Name 

Current Definition: Name of company 

(for consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report). 

Proposed Definition: The name of the 

company that is authorized to make 

sales as indicated in the company’s 

FERC tariff(s). This name may be the 

same as the Company Name of the 

Respondent. 

Field Number 3: Company Duns 

Number 

Current Definition: DUNS number for 

company unique identification. 

Proposed Definition: The unique nine 

digit number assigned by Dun and 

Bradstreet to the company identified in 

Field 2. 

Field Number 4: Contact Name 

Current Definition: Name of contact(s) 

for the filing. 

Proposed Definition: The name of the 

contact for the company authorized to 

make sales as indicated in the 

company’s FERC tariff(s). This name 

may be the same as the Company Name 

of the Respondent. 

Field Number 5: Contact Title 

Current Definition: Title of contact. 

Proposed Definition: Title of contact 

identified in Field Number 4. 

Field Number 6: Contact Address 

Current Definition: Street address for 

contact. 

Proposed Definition: Street address 

for contact identified in Field Number 4. 

Field Number 7: Contact City 

Current Definition: Contact city. 

Proposed Definition: Contact city for 

the contact identified in Field Number 

4. 

Field Number 8: Contact State 

Current Definition: Two character 

state or province abbreviation. 

Proposed Definition: Two character 

state or province abbreviations for the 

contact identified in Field Number 4. 

Field Number 9: Contact Zip 

Current Definition: Contact zip code. 

Proposed Definition: Zip code for the 

contact identified in Field Number 4. 

Field Number 10: Contact Country 

Name 

Current Definition: Country (USA, 

Canada, Mexico or United Kingdom) for 

contact address. 

Proposed Definition: Country (USA, 

Canada, Mexico, or United Kingdom) for 

contact address identified in Field 

Number 4. 

Field Number 11: Contact Phone 

Current Definition: Phone number of 

contact. 

Proposed Definition: Phone number of 

contact identified in Field Number 4. 

Field Number 12: Contact Email 

Current Definition: E-mail address of 

contact. 

Proposed Definition: E-mail address 

of contact identified in Field Number 4. 


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Field Number 13: Filing Quarter 

Current Definition: The period for 

which the Electric Quarterly Report is 

being submitted. 

Proposed Definition: 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) 

Agent Data 

Field Number 1: Filer Unique Identifier 

Current Definition: None 

Proposed Definition: FA (Filing 

Agent)—An identifier (i.e., ‘‘FA1’’) used 

to designate a record containing Agent 

identification information in a commadelimited (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. 

Field Number 2: Company Name 

Current Definition: Name of company 

(for consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report). 

Proposed Definition: The name of the 

entity completing the EQR filing. The 

Agent’s Company Name need not be the 

name of a company under Commission 

jurisdiction. 

Field Number 3: Company Duns 

Number 

Current Definition: DUNS number for 

company unique identification. 

Proposed Definition: The unique nine 

digit number assigned by Dun and 

Bradstreet to the company identified in 

Field 2. 

Field Number 4: Contact Name 

Current Definition: Name of contact(s) 

for the filing. 

Proposed Definition: Name of the 

contact for the Agent, usually the person 

who prepares the filing. 

Field Number 5: Contact Title 

Current Definition: Title of contact. 

Proposed Definition: Title of contact 

identified in Field Number 4. 

Field Number 6: Contact Address 

Current Definition: Street address for 

contact. 

Proposed Definition: Street address 

for contact identified in Field Number 4. 

Field Number 7: Contact City 

Current Definition: Contact city. 

Proposed Definition: City for the 

contact identified in Field Number 4. 

Field Number 8: Contact State 

Current Definition: Two character 

state or province abbreviation. 

Proposed Definition: Two character 

state or province abbreviations for the 

contact identified in Field Number 4. 

Field Number 9: Contact Zip 

Current Definition: Contact zip code. 

Proposed Definition: Zip code for the 

contact identified in Field Number 4. 

Field Number 10: Contact Country 

Name 

Current Definition: Country (USA, 

Canada, Mexico or United Kingdom) for 

contact address. 

Proposed Definition: Country (USA, 

Canada, Mexico, or United Kingdom) for 

contact address identified in Field 

Number 4. 

Field Number 11: Contact Phone 

Current Definition: Phone number of 

contact. 

Proposed Definition: Phone number of 

contact identified in Field Number 4. 

Field Number 12: Contact Email 

Current Definition: E-mail address of 

contact. 

Proposed Definition: E-mail address 

of contact identified in Field Number 4. 

Field Number 13: Filing Quarter 

Current Definition: The period for 

which the Electric Quarterly Report is 

being submitted. 

Proposed Definition: A six digit 

reference number used by the EQR 

software to indicate the quarter and year 

of the filing for the purpose of importing 

data from csv files. The first 4 numbers 

represent the year (e.g. 2007). The last 

2 numbers represent the last month of 

the quarter (e.g. 03 = 1st quarter; 

06 = 2nd quarter, 09 = 3rd quarter, 

12 = 4th quarter) 

CONTRACT DATA: 

Field Number 14: Contract Unique ID 

Current Definition: None. 

Proposed Definition: An identifier 

beginning with the letter ‘‘C’’ and 

followed by a number (e.g., ‘‘C1’’, ‘‘C2’’) 

used to designate a record containing 

contract information in a commadelimited (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. 

Field Number 15: Seller Company Name 

Current Definition: Name of company 

(For consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report.) 

Proposed Definition: 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). 

Field Number 16: Customer Company 

Name 

Current Definition: Name of company 

(For consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report.) 

Proposed Definition: The name of the 

counterparty to the contract. 

Field Number 17: Customer DUNS 

Number 

Current Definition: DUNS Number for 

Company Unique Identification. 

Proposed Definition: The unique nine 

digit number assigned by Dun and 

Bradstreet to the company identified in 

Field Number 16. 

Field Number 18: Contract Affiliate 

Current Definition: This is a flag to 

determine if the customer is an affiliate. 

Set to Yes if the customer is an affiliate 

of the provider. 

Proposed Definition: The customer is 

an affiliate if it controls, is controlled by 

or is under common control with the 

seller, and includes a division that 

operates as a functional unit. 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. 

Field Number 19: FERC Tariff Reference 

Current Definition: Valid Entries: 

FERC’s designation, e.g., ‘‘FERC Electric 

Tariff, Second Revised Volume No. 5, 

Schedule 2;’’ or ‘‘FERC Electric Rate 

Schedule No. 126.’’

Proposed Definition: The FERC tariff 

reference cites the document that 

specifies the terms and conditions 

under which a Seller is authorized to 

make transmission sales or power sales 

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. 

Field Number 20: Contract Service 

Agreement ID 

Current Definition: Unique (company) 

name given to each service agreement. 

It may be the number assigned by FERC 

for those service agreements that have 

been filed and approved by the 

Commission, or it can be an internal 

numbering system. 

Proposed Definition: Unique 

identifier given to each service 


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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. 

Field Number 21: Contract Execution 

Date 

Current Definition: The date the 

contract was signed. If the parties signed 

on different dates, or there are different 

contract amendments, the latest date 

signed. 

Proposed Definition: The date the 

contract was signed. If the parties signed 

on different dates, or there are contract 

amendments, use the most recent date 

signed. 

Field Number 22: Contract 

Commencement Date 

Current Definition: The first date the 

contract was effective—frequently the 

first date of service under a contract. 

Proposed Definition: The date the 

contract was effective. If it is not 

specified in the contract, the first date 

of service under the contract. 

Field Number 23: Contract Termination 

Date 

Current Definition: The date specified 

(if any) in the contract that the contract 

will expire of its own terms. 

Proposed Definition: The date that the 

contract expires. 

Field Number 24: Actual Termination 

Date 

Current Definition: The date the 

contract actually terminates. 

Proposed Definition: No Change. 

Field Number 25: Extension Provision 

Description 

Current Definition: Description of 

extension provision. This field would 

contain Text—for example 

‘‘Automatically renewed until 

canceled.’’

Proposed Definition: Description of 

terms that provide for the continuation 

of the contract. 

Field Number 26: Class Name 

Current Definition: Name of class. 

Valid entries are F—Firm, NF—NonFirm, UP—Unit Power Sale, BA—

Billing Adjustment, and N/A—Not 

Applicable. 

Proposed Definition: 

• F—Firm: For transmission sales, 

service or product that always has 

priority over non-firm service. For 

power sales, service or product that is 

not interruptible for economic reasons. 

• NF—Non-Firm: For transmission 

sales, 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. An energy 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. 

• UP—Unit Power Sale: Designates a 

dedicated sale of energy and capacity 

from one or more than one generation 

unit(s). 

• N/A—Not Applicable: To be used 

only when the other available Class 

Names do not apply. 

Field Number 27: Term Name 

Current Definition: Name for term. 

LT = Long-Term (≥ one year), ST = 

Short-Term (< one year). 

Proposed Definition: Contracts with 

durations of one year or greater are longterm. Contracts with shorter durations 

are short-term. 

Field Number 28: Increment Name 

Current Definition: None. 

Proposed Definition: 

• H—Hourly: Terms of the contract (if 

specifically noted in the contract) set for 

up to 6 consecutive hours (≤ 6 

consecutive hours). 

• D—Daily: Terms of the contract (if 

specifically noted in the contract) set for 

more than 6 and up to 36 consecutive 

hours (> 6 and ≤ 36 consecutive hours). 

• W–Weekly: Terms of the contract (if 

specifically noted in the contract) set for 

over 36 consecutive hours and up to 168 

consecutive hours (> 36 and ≤ 168 

consecutive hours). 

• M—Monthly: Terms of the contract 

(if specifically noted in the contract) set 

for more than 168 consecutive hours up 

to one month (> 168 consecutive hours 

and ≤ 1 month). 

• S—Seasonal: Terms of the contract 

(if specifically noted in the contract) set 

for greater than one month and less than 

365 consecutive days (> 1 month and 

< 1 year). 

• Y—Yearly: Terms of the contract (if 

specifically noted in the contract) set for 

one year or more (≤ 1 year). 

• N/A—Not Applicable: Terms of the 

contract do not specify an increment. 

Field Number 29: Increment Peaking 

Name 

Current Definition: Name for 

increment peaking. For product, 

services, or transaction[s] that are 

identified as P = On Peak, OP = OffPeak, FP = Full Period, N/A = Not 

Applicable, Undefined. 

Proposed Definition: 

• FP—Full Period: The product 

described may be sold during all hours 

under the contract. 

• OP—Off-Peak: The product 

described may be sold only during those 

hours designated as off-peak in the 

NERC region of the point of delivery. 

• P—Peak: The product described 

may be sold only during those hours 

designated as on-peak in the NERC 

region of the point of delivery. 

• N/A—Not Applicable: To be used 

only when the increment peaking name 

is not specified in the contract. 

Field Number 30: Product Type Name 

Current Definition: A product is 

something being bought and sold, a type 

of service or standard agreement. The 

‘‘product type name’’ includes: T = 

Electric Transmission, MB = Market 

Based Power, CB = Cost Based Power, 

S = Services—Other. 

Proposed Definition: 

• CB—Cost-Based: Energy or capacity 

sold under a FERC-approved cost-based 

rate tariff. 

• MB—Market-Based: Energy sold 

under the seller’s FERC-approved 

market-based rate tariff. 

• T—Transmission: The product is 

sold under a FERC-approved 

transmission tariff. 

• Other: The product cannot be 

characterized by the other product type 

names. 

Field Number 31: Product Name 

Current Definition: A product is 

something being bought and sold, a type 

of service or standard agreement. 

Proposed Definition: Description of 

the product being offered. (Refer to 

Attachment A-Appendix A for an 

acceptable list of product names for this 

field). 

Field Number 32: Quantity 

Current Definition: Product quantity 

for the contract item identified. 

Proposed Definition: Quantity for the 

contract product identified. 

Field Number 33: Units 

Current Definition: The unit of 

measurement for the quantity and rates 

represented. Examples include KW, 

MW, and MWH. 

Proposed Definition: Measure stated 

in the contract for the product sold 

(Refer to Attachment A-Appendix E for 

an acceptable list of units for this field). 

Field Number 34: Rate 

Current Definition: Rate charged for 

this product per unit. Used when a 

single rate is designated for a product. 

Proposed Definition: The charge for 

the product per unit as stated in the 

contract. 


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Field Number 35: Rate Minimum 

Current Definition: Minimum rate to 

be charged per the contract, if a range 

is specified. 

Proposed Definition: No Change. 

Field Number 36: Rate Maximum 

Current Definition: Maximum rate to 

be charged per the contract, if a range 

is specified. 

Proposed Definition: No Change. 

Field Number 37: Rate Description 

Current Definition: Text description 

of rate. May reference FERC tariff, or, if 

a discounted or negotiated rate, include 

algorithm. 

Proposed Definition: No Change. 

Field Number 38: Rate Units 

Current Definition: The unit of 

measurement for the quantity and rates 

represented. Examples include KW, 

MW, and MWH. 

Proposed Definition: Measure stated 

in the contract for the product sold. 

(Refer to Attachment A-Appendix F for 

an acceptable list of rate units for this 

field). 

Field Number 39: Point of Receipt 

Balancing Authority (PORBA) 

Current Definition: The registered 

control area abbreviation used in OASIS 

applications. 

Proposed Definition: The registered 

NERC Balancing Authority (formerly 

called NERC Control Area) abbreviation 

used in OASIS applications or ‘‘Hub’’ if 

point of receipt is at a restricted trading 

hub. 

Field Number 40: Point of Receipt 

Specific Location (PORSL) 

Current Definition: The specific 

location for the point of receipt (POR) as 

spelled out in the contract. Examples 

include a named sub-station or 

generation plant. 

Proposed Definition: The specific 

location at which the product is 

received if designated in the contract. If 

receipt occurs at a trading hub, a 

standardized hub name must be used. 

(Refer to Attachment A-Appendix C for 

an acceptable list of locations for this 

field). 

Field Number 41: Point of Delivery 

Balancing Authority (PODBA) 

Current Definition: The registered 

control area abbreviation used in OASIS 

applications. 

Proposed Definition: The registered 

NERC Balancing Authority (formerly 

called NERC Control Area) abbreviation 

used in OASIS applications or ‘‘Hub’’ if 

point of receipt is at a restricted trading 

hub. 

Field Number 42: Point of Delivery 

Specific Location (PODSL) 

Current Definition: The specific 

location for the point of delivery (POD) 

as spelled out in the contract. Examples 

include a named sub-station or 

generation plant. 

Proposed Definition: The specific 

location at which the product is 

delivered if designated in the contract. 

If receipt occurs at a trading hub, a 

standardized hub name must be used. 

(Refer to Attachment A-Appendix C for 

an acceptable list of hubs for this field). 

Field Number 43: Begin Date 

Current Definition: Beginning date 

[of] for the product specified (this 

should be specified here as explicitly as 

it is specified in the contract, i.e., 

yyyy+mo+dd+hh+mm+ss+tz). TZ = 

time zone. 

Proposed Definition: First date for the 

sale of the product at the rate specified. 

Field Number 44: End Date 

Current Definition: Ending date for 

the product specified (this should be 

specified here as explicitly as it is 

specified in the contract, i.e., 

yyyy+mo+dd+hh+mm+ss+tz). TZ = 

time zone. 

Proposed Definition: Last date for the 

sale of the product at the rate specified. 

Field Number 45: Time Zone. 

Current Definition: None. 

Proposed Definition: The time zone in 

which the sales will be made under the 

contract. (Refer to Attachment AAppendix D for an acceptable list of 

time zones for this field). 

TRANSACTION DATA 

Field Number 46: Transaction Unique 

ID 

Current Definition: None. 

Proposed Definition: 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 commadelimited (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. 

Field Number 47: Seller Company Name 

Current Definition: Name of company 

(For consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report.) 

Proposed Definition: 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). 

Field Number 48: Customer Company 

Name 

Current Definition: Name of company. 

(For consistency sake, it must be 

represented the same as it is listed in the 

DUNS Report.) 

Proposed Definition: The name of the 

counterparty to the contract. 

Field Number 49: Customer DUNS 

Number 

Current Definition: DUNS Number for 

Company Unique Identification. 

Proposed Definition: The unique nine 

digit number assigned by Dun and 

Bradstreet to the counterparty to the 

contract. 

Field Number 50: FERC Tariff Reference 

Current Definition: Valid Entries: 

FERC’s designation, e.g., ‘‘FERC Electric 

Tariff, Second Revised Volume No. 5, 

Schedule 2;’’ or ‘‘FERC Electric Rate 

Schedule No. 126.’’

Proposed Definition: The FERC tariff 

reference cites the document that 

specifies the terms and conditions 

under which a Seller is authorized to 

make transmission sales or power sales 

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. 

Field Number 51: Contract Service 

Agreement ID 

Current Definition: Unique (company) 

name given to each service agreement. 

It may be the number assigned by FERC 

for those service agreements that have 

been filed and approved by the 

Commission, or it can be an internal 

numbering system. 

Proposed Definition: 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. 

Field Number 52: Transaction Unique 

Identifier 

Current Definition: Unique reference 

number assigned by the seller for each 

transaction. 


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Proposed Definition: No Change. 

Field Number 53: Transaction Begin 

Date 

Current Definition: Transaction begin 

date must be prior to the end of the 

reporting quarter. Date must contain 

hours, minutes, seconds, and time zone 

(MM.DD.YYYY.HH.MM.SS.TZ). Where 

minutes and seconds are not provided, 

default to zeros. 

Proposed Definition: First date and 

time the product is sold during the 

quarter at the specified price. 

Field Number 54: Transaction End Date 

Current Definition: Transaction end 

date and time must be after the 

beginning of the reporting quarter. Date 

must contain hours, minutes, seconds, 

and time zone 

(MM.DD.YYYY.HH.MM.SS.TZ). Where 

minutes and seconds are not provided, 

default to zeros. 

Proposed Definition: Last date and 

time the product is sold during the 

quarter at the specified price. 

Field Number 55: Time Zone. 

Current Definition: None. 

Proposed Definition: The time zone in 

which the sales will be made under the 

contract. (Refer to Attachment AAppendix D for an acceptable list of 

time zones for this field). 

Field Number 56: Point of Delivery 

Balancing Authority (PODBA) 

Current Definition: The registered 

control area abbreviation used in OASIS 

applications. 

Proposed Definition: The registered 

NERC Balancing Authority (formerly 

called NERC Control Area) abbreviation 

used in OASIS applications or ‘‘Hub’’ if 

point of receipt is at a restricted trading 

hub. 

Field Number 57: Point of Delivery 

Specific Location (PODSL) 

Current Definition: The specific 

location for the point of delivery (POD) 

as spelled out in the contract. Examples 

include sub-station or generation plant. 

Proposed Definition: The specific 

location at which the product is 

delivered. If receipt occurs at a trading 

hub, a standardized hub name must be 

used. (Refer to Attachment A-Appendix 

C for an acceptable list of hubs for this 

field). 

Field Number 58: Class Name 

Current Definition: Name of class. 

Valid entries are F-Firm, NF-Non-Firm, 

UP-Unit Power Sale, BA-Billing 

Adjustment, and N/A-Not Applicable. 

Proposed Definition: 

• F-Firm: For transmission sales, 

service or product that always has 

priority over non-firm service. For 

power sales, service or product that is 

not interruptible for economic reasons. 

• NF-Non-Firm: For transmission 

sales, 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 

transmission service. An energy 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. 

• UP-Unit Power Sale: Designates a 

dedicated sale of energy and capacity 

from one or more than one generation 

unit(s). 

• BA-Billing Adjustment: Incremental 

positive or negative material change to 

previous EQR totals. 

• N/A-Not Applicable: To be used 

only when the other available class 

names do not apply. 

Field Number 59: Term Name 

Current Definition: Name for term. LT 

= Long-Term (> one year), ST = ShortTerm (≤ one year). 

Proposed Definition: Power sales 

transactions with durations one year or 

greater are long-term. Transactions with 

shorter durations are short-term. 

Field Number 60: Increment Name 

Current Definition: Name of 

increment which would be one of the 

following: H = Hourly, D = Daily, W = 

Weekly, M = Monthly, Y = Yearly (or 

annually) or {registered}. (New items 

may be included in this list provided 

they are registered with FERC prior to 

their inclusion in the filing.) 

Proposed Definition: 

• 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. 

• D-Daily: Terms of the particular sale 

set for more than 6 and up to 36 

consecutive hours (> 6 and ≤ 36 

consecutive hours) Includes sales over a 

peak or off-peak block during a single 

day. 

• W-Weekly: Terms of the particular 

sale set for over 36 consecutive hours 

and up to 168 consecutive hours (> 36 

and ≤ 168 consecutive hours). Includes 

sales for a full week and sales for peak 

and off-peak blocks over a particular 

week. 

• M-Monthly: Terms of the particular 

sale set for set for more than 168 

consecutive hours up to one month (> 

168 consecutive hours and ≤ 1 month). 

Includes sales for full month or multiweek sales during a given month. 

• S-Seasonal: Terms of the specific 

sales set for greater than one month and 

less than 365 consecutive days (> 1 

month and < 1 year). 

• 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 indexed). 

• N/A-Not Applicable: To be used 

only when other available increment 

names do not apply. 

Field Number 61: Increment Peaking 

Name 

Current Definition: Name for 

increment peaking. For product, 

services, or transaction[s] that are 

identified as P = On Peak, OP = OffPeak, FP = Full Period, N/A = Not 

Applicable, Undefined. 

Proposed Definition: 

• FP—Full Period: The product 

described may be sold during all hours 

under the contract. 

• OP—Off-Peak: The product 

described may be sold only during those 

hours designated as off-peak in the 

NERC region of the point of delivery. 

• P—Peak: The product described 

may be sold only during those hours 

designated as on-peak in the NERC 

region of the point of delivery. 

• N/A—Not Applicable: To be used 

only when other available increment 

peaking names do not apply. 

Field Number 62: Product Name 

Current Definition: A product is 

something being bought and sold, a type 

of service or standard agreement. 

Proposed Definition: Description of 

product being offered. (Refer to 

Attachment A-Appendix A for an 

acceptable list of product names for this 

field). 

Field Number 63: Transaction Quantity 

Current Definition: The quantity of 

the product in this transaction. This 

could be a whole number or it could 

include decimals. 

Proposed Definition: The quantity of the 

product in this transaction. 

Field Number 64: Price 

Current Definition: Rate charged for 

this item per unit. Used with contract 

data when a single rate is designated for 

a product. Used with transaction data to 

designate the transaction period’s 

weighted average actual rate. 

Proposed Definition: Price charged for 

the product per unit. 

Field Number 65: Rate Units 

Current Definition: The unit of 

measurement for the quantity and rates 

represented. Examples include KW, 

MW, and MWH. 

Proposed Definition: Measure 

appropriate to the price of the product 


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sold. (Refer to Attachment A-Appendix 

F for an acceptable list of rate units for 

this field). 

Field Number 66: Total Transmission 

Charge 

Current Definition: State N/A if 

transmission is not provided by the 

selling entity, else this represents the 

total transmission charge associated 

with the identified power sale 

transaction. 

Proposed Definition: Payments 

received for transmission services when 

explicitly identified. 

Field Number 67: Total Transaction 

Charge 

Current Definition: Total revenue for 

transaction, including for the 

commodity and all other services 

related to the commodity sale under the 

terms of the contract, including bundled 

ancillary and transmission services 

provided by the respondent or others. 

This is in dollars and cents. 

Proposed Definition: Transaction 

Quantity (Field 63) times Price (Field 

64) plus Total Transmission Charge 

(Field 66). 

PRODUCT NAME APPENDIX 

BLACK START SERVICE 

Current Definition: 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) 

Proposed Definition: No Change. 

BOOKED OUT POWER 

Energy or capacity contractually 

committed bilaterally for delivery but 

not actually delivered due to some 

offsetting or countervailing trade 

(Transaction only). 

Proposed Definition: No Change. 

CAPACITY 

A quantity of demand that is charged 

on a $/KW or $/MW basis. 

Proposed Definition: No Change. 

CAPACITY REASSIGNMENT 

Current Definition: None. 

Proposed Definition: An agreement 

under which a transmission customer 

sells, assigns or transfers all or portion 

of its rights to an eligible customer. 

CUSTOMER CHARGE 

Current Definition: Fixed contractual 

charges assessed on a per customer basis 

that could include billing service. 

Proposed Definition: No Change. 

DIRECT ASSIGNMENT FACILITIES 

CHARGE 

Charges for facilities or portions of 

facilities that are constructed or used for 

the sole use/benefit of a particular 

customer. 

Proposed Definition: No Change. 

EMERGENCY ENERGY 

Contractual provisions to supply 

energy or capacity to another entity 

during critical situations. 

Proposed Definition: No Change. 

ENERGY 

A quantity of electricity that is sold or 

transmitted over a period of time. 

Proposed Definition: No Change. 

ENERGY IMBALANCE 

Service provided when a difference 

occurs between the scheduled and the 

actual delivery of energy to a load 

obligation. 

Proposed Definition: No Change. 

EXCHANGE 

(Previously ‘‘Exchange Agreement’’.) 

Transaction whereby the receiver 

accepts delivery of energy for a 

supplier’s account and returns energy 

later at times, rates, and in amounts as 

mutually agreed. 

Proposed Definition: The product 

name is being changed from ‘‘Exchange 

Agreement’’ to ‘‘Exchange.’’ However, 

the underlying definition is not 

proposed to be changed. 

FUEL CHARGE 

Current Definition: Charge based on 

the cost or amount of fuel used for 

generation. 

Proposed Definition: No Change. 

GRANDFATHERED BUNDLED 

Services provided for bundled 

transmission, ancillary services and 

energy under contracts effective prior to 

Order No. 888’s OATTs. 

Proposed Definition: No Change. 

INTERCONNECTION AGREEMENT 

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. 

Proposed Definition: No Change. 

MEMBERSHIP AGREEMENT 

Agreement to participate and be 

subject to rules of a system operator. 

Proposed Definition: No Change. 

MUST RUN AGREEMENT 

An agreement that requires a unit to 

run. 

Proposed Definition: No Change. 

NEGOTIATED-RATE TRANSMISSION 

Transmission performed under a 

negotiated rate contract (applies only to 

merchant transmission companies). 

Proposed Definition: No Change. 

NETWORK 

Transmission service under contract 

providing network service. 

Proposed Definition: No Change. 

NETWORK OPERATING AGREEMENT 

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. 

Proposed Definition: No Change. 

OTHER 

Product name not otherwise included. 

Proposed Definition: No Change. 

POINT-TO-POINT AGREEMENT 

Transmission service under contract 

between specified Points of Receipt and 

Delivery. 

Proposed Definition: No Change. 

REACTIVE SUPPLY & VOLTAGE 

CONTROL 

Production or absorption of reactive 

power to maintain voltage levels on 

transmission systems (Ancillary 

Service). 

Proposed Definition: No Change. 

REAL POWER TRANSMISSION LOSS 

The loss of energy, resulting from 

transporting power over a transmission 

system. 

Proposed Definition: No Change. 

REGULATION & FREQUENCY 

RESPONSE 

Service providing for continuous 

balancing of resources (generation and 

interchange) with load, and for 

maintaining scheduled interconnection 

frequency by committing on-line 

generation where output is raised or 

lowered as necessary to follow the 

moment-by-moment changes in load 

(Ancillary Service). 

Proposed Definition: 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). 


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REQUIREMENTS SERVICE 

Current Definition: Firm, loadfollowing 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.) 

Proposed Definition: No Change. 

SCHEDULE SYSTEM CONTROL & 

DISPATCH 

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). 

Proposed Definition: No Change. 

SPINNING RESERVE 

Unloaded synchronized generating 

capacity that is immediately responsive 

to system frequency and that is capable 

of being loaded in a short time period 

(Ancillary Service). 

Proposed Definition: Unloaded 

synchronized generating capacity that is 

immediately responsive to system 

frequency and that is capable of being 

loaded in a short time period or nongeneration resources capable of 

providing this service (Ancillary 

Service). 

SUPPLEMENTAL RESERVE 

Current Definition: Service needed to 

serve load in the event of a system 

contingency, available with greater 

delay than SPINNING RESERVE 

(Ancillary Service). 

Proposed Definition: 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 nongeneration resources capable of 

providing this service (Ancillary 

Service). 

SYSTEM OPERATING AGREEMENTS 

Current Definition: 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. 

Proposed Definition: No Change. 

TOLLING ENERGY 

Current Definition: None. 

Proposed Definition: 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 

Current Definition: The agreement 

that establishes the terms and 

conditions under which a transmission 

owner transfers to an ISO operational 

control over designated transmission 

facilities. 

Proposed Definition: The agreement 

that establishes the terms and 

conditions under which a transmission 

owner transfers operational control over 

designated transmission facilities. 

UPLIFT 

Current Definition: None. 

Proposed Definition: A make-whole 

payment by an RTO/ISO to the EQR 

filer. 

Balancing Authority Appendix: 

Ameren Native Load—No Change 

Alabama Electric Cooperative, Inc.—No 

Change 

Associated Electric Cooperative, Inc.—

No Change 

Alberta Electric System Operator—No 

Change 

AESC, LLC—Wheatland CIN-Revised 

NERC Definition—AEWC, 

Allegheny Energy Supply 

Company, LLC—Wheatland CIN, 

ECAR 

Alliant Energy—CA—ALTE-Revised 

NERC Definition—ALTE, Alliant 

Energy Corporate Services, Inc.—

East, MRO 

Alliant Energy—CA—ALTW—Revised 

NERC Definition—ALTW, Alliant 

Energy Corporate Services, Inc.—

West, MRO 

Ameren Transmission—Revised NERC 

Definition—AMRN, Ameren 

Transmission (legal name Ameren 

Services Company), SERC 

Avista Corp.—Revised NERC 

Definition—AVA, Avista Corp., 

WSCC 

Arizona Public Service Company—

Revised NERC Definition—AZPS, 

Arizona Public Service Company, 

WSCC 

CECD, LLC—Batesville—No Change 

British Columbia Transmission 

Corporation—No Change 

Bonneville Power Administration 

Transmission—Revised NERC 

Definition—BPAT, Bonneville 

Power Administration 

Transmission, WSCC 

Big Rivers Electric Corp.—Revised 

NERC Definition—BREC, Big Rivers 

Electric Corp., SERC 

Comision Federal de Electricidad—

Revised NERC Definition—CFE, 

Comision Federal de Electricidad, 

WSCC 

Chelan County PUD—Revised NERC 

Definition—CHPD, Chelan County 

PUD, WSCC 

Central Illinois Light Co—Revised NERC 

Definition—CILC, Central Illinois 

Light Co, SERC 

Cinergy Corporation—No Change 

California Independent System 

Operator—Revised NERC 

Definition—CISO, California 

Independent System Operator 

(CAISO), WSCC 

Cleco Power LLC—No Change 

CECD, LLC—No Change 

Michigan Electric Coordinated System—

Consumers—No Change 

Carolina Power & Light Company—

CPLE—Revised NERC Definition—

CPLE, Carolina Power & Light 

Company—East, SERC 

Carolina Power & Light Company—

CPLW—Revised NERC Definition—

CPLW, Carolina Power & Light 

Company—West, SERC 

Central and Southwest—No Change 

Columbia Water & Light—Revised NERC 

Definition—CWLD, Central and 

Southwest, SERC 

City Water Light & Power—Revised 

NERC Definition—CWLP, City 

Water Light & Power, RFC 

DECA, LLC—Arlington Valley—Revised 

NERC Definition—DEAA, CECD, 

LLC—Arlington Valley, WSCC 

Michigan Electric Coordinated System—

Detroit Edison—No Change 

DECA, LLC—North Little Rock—

Revised NERC Definition—DENL, 

ECD, LLC—North Little Rock, SERC 

CECD, LLC—City of Ruston, LA—No 

Change 

P.U.D. No. 1 of Douglas County—

Revised NERC Definition—DOPD, 

P.U.D. No. 1 of Douglas County, 

WSCC 

Dairyland Power Cooperative—Revised 

NERC Definition—DPC, Dairyland 

Power Cooperative, MRO 

Duke Energy Corporation—Revised 

NERC Definition—DUK, Duke 

Power Company LLC 

(Transmission), SERC 

Empire District Electric Co., The—No 

Change 

Electric Energy, Inc.—No Change 

Entergy—No Change 

East Kentucky Power Cooperative, 

Inc.—Revised NERC Definition—

EKPC, East Kentucky Power 

Cooperative, Inc., SERC 

El Paso Electric—Revised NERC 

Definition—EPE, El Paso Electric, 

WSCC 

ERCOT ISO—No Change 

American Transmission Systems, Inc.—

No Change 


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26112 Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 

Florida Municipal Power Pool—No 

Change 

Florida Power Corporation—No Change 

Florida Power & Light—No Change 

GridAmerica—No Change 

Grant County PUD No.2—Revised NERC 

Definition—GCPD, Grant County 

PUD No.2, WSCC 

Grand River Dam Authority—No 

Change 

Great River Energy—Revised NERC 

Definition—GRE, Great River 

Energy, MRO 

Great River Energy—No Change 

Great River Energy—No Change 

Great River Energy—No Change 

CECD, LLC—Gila River—No Change 

Georgia System Operations 

Corporation—No Change 

Georgia Transmission Corporation—No 

Change 

Gainesville Regional Utilities—No 

Change 

Hoosier Energy—No Change 

CECD, LLC—Harquahalla—No Change 

Hydro—Quebec, TransEnergie—No 

Change 

City of Homestead—No Change 

Imperial Irrigation District—Revised 

NERC Definition—IID, Imperial 

Irrigation District, WSCC 

City of Independence P&L Dept.—No 

Change 

Illinois Power Co.—Revised NERC 

Definition—IP, Illinois Power Co., 

SERC 

Idaho Power Company—Revised NERC 

Definition—IPCO, Idaho Power 

Company, WSCC 

Indianapolis Power & Light Company—

No Change 

Illinois Power Co.—No Change 

ISO New England Inc.—No Change 

JEA—No Change 

Board of Public Utilities—No Change 

Kansas City Power & Light, Co—No 

Change 

Lafayette Utilities System—No Change 

Louisiana Generating, LLC—No Change 

Los Angeles Department of Water and 

Power—Revised NERC Definition—

LDWP, Los Angeles Department of 

Water and Power, WSCC 

Louisiana Energy & Power Authority—

No Change 

Lincoln Electric System—No Change 

LG&E Energy Transmission Services—

Revised NERC Definition—LGEE, 

E.ON U.S. Services Inc., RFC 

Montana—Dakota Utilities Co.—No 

Change 

MidAmerican Energy Company—No 

Change 

Michigan Electric Coordinated System—

Revised NERC Definition—MECS, 

Michigan Electric Coordinated 

System, RFC 

Madison Gas and Electric Company—

Revised NERC Definition—MGE, 

Madison Gas and Electric Company, 

MRO 

MHEB, Transmission Services—No 

Change 

Midwest ISO—No Change 

Westar Energy/Missouri Joint Municipal 

Electric Utility Commission—No 

Change 

Minnesota Power, Inc.—No Change 

Aquila Networks—MPS-Revised NERC 

Definition—MPS, Aquila 

Networks—Missouri Public Service, 

SPP 

Muscatine Power and Water—No 

Change 

New Brunswick Power Corporation—No 

Change 

Nevada Power Company—Revised 

NERC Definition—NEVP, Nevada 

Power Company, WSCC 

New Horizons Electric Cooperative—No 

Change 

Northern Indiana Public Service 

Company—Revised NERC 

Definition—NIPS, Northern Indiana 

Public Service Company, RFC 

Nebraska Public Power District—No 

Change 

Utilities Commission, City of New 

Smyrna Beach—No Change 

Northern States Power Company—

Revised NERC Definition—NSP, 

Northern States Power Company, 

MRO 

NorthWestern Energy—No Change 

New York Independent System 

Operator—No Change 

Oklahoma Gas and Electric—No Change 

Ontario—Independent Electricity 

System Operator—No Change 

OPPD CA/TP—No Change 

Otter Tail Power Company—Revised 

NERC Definition—OTP, Otter Tail 

Power Company, MRO 

Ohio Valley Electric Corporation—

Revised NERC Definition—OVEC, 

Ohio Valley Electric Corporation, 

RFC 

PacifiCorp—East—Revised NERC 

Definition—PACE, PacifiCorp—

East, WSCC 

PacifiCorp—West—Revised NERC 

Definition—PACE, PacifiCorp—West, 

WSCC 

Portland General Electric—Revised 

NERC Definition—PGE, Portland 

General Electric, WSCC 

PJM Interconnection—Revised NERC 

Definition—PJM, PJM 

Interconnection, RFC 

Public Service Company of New 

Mexico—Revised NERC Definition—

PNM, Public Service Company of 

New Mexico, WSCC 

Public Service Company of Colorado—

Revised NERC Definition—PSCO, 

Public Service Company of 

Colorado CA&TP, WSCC 

Puget Sound Energy Transmission—

Revised NERC Definition—PSEI, 

Puget Sound Energy Transmission, 

WSCC 

CECD, LLC—Arkansas—No Change 

Reedy Creek Improvement District—No 

Change 

Santee Cooper—No Change 

South Carolina Electric & Gas 

Company—No Change 

Seattle City Light—Revised NERC 

Definition—SCL, Seattle City Light, 

WSCC 

Seminole Electric Cooperative—No 

Change 

Sunflower Electric Power Corporation—

No Change 

Southeastern Power Administration—

Revised NERC Definition—SEHA, 

Southeastern Power Administration—

Hartwell, SERC 

Southeastern Power Administration—

Revised NERC Definition—SERU, 

Southeastern Power Administration—

Russell, SERC 

Southeastern Power Administration—

Revised NERC Definition—SETH, 

Southeastern Power Administration—

Thermond, SERC 

Southern Indiana Gas & Electric Co.—

Revised NERC Definition—SIGE, 

Southern Indiana Gas & Electric Co., 

RFC 

Southern Illinois Power Cooperative—

Revised NERC Definition—SIPC, 

Southern Illinois Power Cooperative, 

SERC 

South Mississippi Electric Power 

Association—No Change 

South Mississippi Electric Power 

Association—No Change 

Southern Minnesota Municipal Power 

Agency—No Change 

Sacramento Municipal Utility District—

Revised NERC Definition—SMUD, 

Sacramento Municipal Utility District, 

WSCC 

Southern Company Services, Inc.—No 

Change 

Southwestern Power Administration—

No Change 

SaskPower Grid Control Centre—No 

Change 

Sierra Pacific Power Co.—

Transmission—Revised NERC 

Definition—SPPC, Sierra Pacific 

Power Co.—Transmission, WSCC 

Southwestern Public Service 

Company—No Change 

Salt River Project—Revised NERC 

Definition—SRP, Salt River Project, 

WSCC 

Southwest Power Pool—No Change 

City of Tallahassee—No Change 

Tampa Electric Company—No Change 

Tucson Electric Power Company—

Revised NERC Definition—TEPC, 

Tucson Electric Power Company, 

WSCC 

North American Electric Reliability 

Council—No Change 


cprice-sewell on PROD1PC66 with NOTICES
Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 26113 

Turlock Irrigation District—No Change 

TRANSLink Management Company—

No Change 

Tacoma Power—Revised NERC 

Definition—TPWR, Tacoma Power, 

WSCC 

Tennessee Valley Authority ESO—No 

Change 

Upper Peninsula Power Co.—No Change 

Western Area Power Administration—

CM—Revised NERC Definition—

WACM, Western Area Power 

Administration—ColoradoMissouri, WSCC 

Western Area Power Administration—

DSW—Revised NERC Definition—

WALC, Western Area Power 

Administration—Lower Colorado, 

WSCC 

Western Area Power Administration—

UGPR—Revised NERC Definition—

WAUE, Western Area Power 

Administration—Upper Great 

Plains East, MAPP 

Western Area Power Administration—

UGPR—Revised NERC Definition—

WAUW, Western Area Power 

Administration—Upper Great 

Plains West, WSCC 

Wisconsin Energy Corporation—Revised 

NERC Definition—WEC, Wisconsin 

Energy Corporation, RFC 

Western Farmers Electric Cooperative—

No Change 

CECD, LLC—No Change 

Aquila Networks—West Plains 

Dispatch—No Change 

Aquila Networks—WPK—Revised 

NERC Definition—WPEK, Aquila 

Networks—Kansas, SPP 

Wisconsin Public Service Corporation—

Revised NERC Definition—WPS, 

Wisconsin Public Service 

Corporation, MRO 

Westar Energy, Inc.—No Change 

Yadkin, Inc.—No Change 

HUB APPENDIX 

ADHUB 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price (‘‘LMP’’) 

nodes defined by PJM Interconnection, 

LLC as the AEP/Dayton Hub. 

AEP (into) 

Current Definition: None 

Proposed Definition: The set of 

delivery points commonly identified as 

and agreed to by the counterparties to 

constitute delivery into the AEP 

balancing authority. 

AEPGenHub 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price (‘‘LMP’’) 

nodes defined by PJM Interconnection, 

LLC as the AEPGenHub. 

COB 

Current Definition: None 

Proposed Definition: The set of 

delivery points along the CaliforniaOregon commonly identified as and 

agreed to by the counterparties to 

constitute the COB Hub. 

Cinergy (into) 

Current Definition: None 

Proposed Definition: 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) 

Current Definition: None 

Proposed Definition: The aggregated 

Elemental Pricing nodes (‘‘Epnodes’’) 

defined by the Midwest Independent 

Transmission System Operator, Inc., as 

Cinergy Hub (MISO). 

Comed (into) 

Current Definition: None 

Proposed Definition: The set of 

delivery points commonly identified as 

and agreed to by the counterparties to 

constitute delivery into the 

Commonwealth Edison balancing 

authority. 

Entergy (into) 

Current Definition: None 

Proposed Definition: The set of 

delivery points commonly identified as 

and agreed to by the counterparties to 

constitute delivery into the Entergy 

balancing authority. 

FE Hub 

Current Definition: None 

Proposed Definition: The aggregated 

Elemental Pricing nodes (‘‘Epnodes’’) 

defined by the Midwest Independent 

Transmission System Operator, Inc., as 

FE Hub (MISO). 

Four Corners 

Current Definition: None 

Proposed Definition: The set of 

delivery points at the Four Corners 

power plants commonly identified as 

and agreed to by the counterparties to 

constitute the Four Corners Hub. 

Illinois Hub (MISO) 

Current Definition: None 

Proposed Definition: The aggregated 

Elemental Pricing nodes (‘‘Epnodes’’) 

defined by the Midwest Independent 

Transmission System Operator, Inc., as 

Illinois Hub (MISO). 

Mead 

Current Definition: None 

Proposed Definition: 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) 

Current Definition: None 

Proposed Definition: The aggregated 

Elemental Pricing nodes (‘‘Epnodes’’) 

defined by the Midwest Independent 

Transmission System Operator, Inc., as 

Michigan Hub (MISO). 

Mid-Columbia (Mid-C) 

Current Definition: None 

Proposed Definition: 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) 

Current Definition: None 

Proposed Definition: The aggregated 

Elemental Pricing nodes (‘‘Epnodes’’) 

defined by the Midwest Independent 

Transmission System Operator, Inc., as 

Minnesota Hub (MISO). 

NEPOOL (Mass Hub) 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price nodes 

(‘‘LMP’’) defined by ISO New England 

Inc., as Mass Hub. 

NIHUB 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price nodes 

(‘‘LMP’’) defined by PJM 

Interconnection, LLC as the Northern 

Illinois Hub. 

NOB 

Current Definition: None 

Proposed Definition: The set of 

delivery points along the NevadaOregon border commonly identified as 

and agreed to by the counterparties to 

constitute the NOB Hub. 

NP15 

Current Definition: None 

Proposed Definition: 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 

Current Definition: None 

Proposed Definition: The set of 

delivery points commonly identified as 

and agreed to by the counterparties to 

constitute delivery into the 

Northwestern Energy Montana 

balancing authority. 


cprice-sewell on PROD1PC66 with NOTICES
26114 Federal Register / Vol. 72, No. 88 / Tuesday, May 8, 2007 / Notices 

PJM East Hub 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price nodes 

(‘‘LMP’’) defined by PJM 

Interconnection, LLC as the PJM East 

Hub. 

PJM South Hub 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price nodes 

(‘‘LMP’’) defined by PJM 

Interconnection, LLC as the PJM South 

Hub. 

PJM West Hub 

Current Definition: None 

Proposed Definition: The aggregated 

Locational Marginal Price nodes 

(‘‘LMP’’) defined by PJM 

Interconnection, LLC as the PJM 

Western Hub. 

Palo Verde 

Current Definition: None 

Proposed Definition: The switch yard 

at the Palo Verde nuclear power station 

west of Phoenix in Arizona. 

SOCO (into) 

Current Definition: None 

Proposed Definition: The set of 

delivery points commonly identified as 

and agreed to by the counterparties to 

constitute delivery into the Southern 

Company balancing authority. 

SP15 

Current Definition: None 

Proposed Definition: 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) 

Current Definition: None 

Proposed Definition: 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 

Current Definition: None 

Proposed Definition: 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. 

TIME ZONE APPENDIX 

AD—Never previously defined—

Atlantic Daylight 

AP—Never previously defined—

Atlantic Prevailing 

AS—Never previously defined—

Atlantic Standard 

CD—Never previously defined—Central 

Daylight 

CP—Never previously defined—Central 

Prevailing 

CS—Never previously defined—Central 

Standard 

ED—Never previously defined—Eastern 

Daylight 

EP—Never previously defined—Eastern 

Prevailing 

ES—Never previously defined—Eastern 

Standard 

MD—Never previously defined—

Mountain Daylight 

MP—Never previously defined—

Mountain Prevailing 

MS—Never previously defined—

Mountain Standard 

NA—Never previously defined—Not 

Applicable 

PD—Never previously defined—Pacific 

Daylight 

PP—Never previously defined—Pacific 

Prevailing 

PS—Never previously defined—Pacific 

Standard 

UT—Never previously defined—

Universal Time 

UNITS APPENDIX 

KV—Never previously defined—kilovolt 

KVA—Never previously defined—

kilovolt amperes 

KVR—Never previously defined—

kilovar 

KW—Never previously defined—

kilowatt 

KWH—Never previously defined—

kilowatt hour 

KW—DAY—Never previously defined—

kilowatt day 

KW—MO—Never previously defined—

kilowatt month 

KW—WK—Never previously defined—

kilowatt week 

KW—YR—Never previously defined—

kilowatt year 

MVAR—YR—Never previously 

defined—megavar year 

MW—Never previously defined—

megawatt 

MWH—Never previously defined—

megawatt hour 

MW—DAY—Never previously 

defined—megawatt day 

MW—MO—Never previously defined—

megawatt month 

MW—WK—Never previously defined—

megawatt week 

MW—YR—Never previously defined—

megawatt year 

RKVA—Never previously defined—

reactive kilovolt amperes 

FLAT RATE—Never previously 

defined—flat rate 

RATE UNITS APPENDIX 

$/KV—Never previously defined—

dollars per kilovolt 

$/KVA—Never previously defined—

dollars per kilovolt amperes 

$/KVR—Never previously defined—

dollars per kilovar 

$/KW—Never previously defined—

dollars per kilowatt 

$/KWH—Never previously defined—

dollars per kilowatt hour 

$/KW—DAY—Never previously 

defined—dollars per kilowatt day 

$/KW—MO—Never previously 

defined—dollars per kilowatt 

month 

$/KW—WK—Never previously 

defined—dollars per kilowatt week 

$/KW—YR—Never previously 

defined—dollars per kilowatt year 

$/MW—Never previously defined—

dollars per megawatt 

$/MWH—Never previously defined—

dollars per megawatt hour 

$/MW—DAY—Never previously 

defined—dollars per megawatt day 

$/MW—MO—Never previously 

defined—dollars per megawatt 

month 

$/MW—WK—Never previously 

defined—dollars per megawatt 

week 

$/MW—YR—Never previously 

defined—dollars per megawatt year 

$/MVAR—YR—Never previously 

defined—dollars per megavar year 

$/RKVA—Never previously defined—

dollars per reactive kilovar amperes 

CENTS—Never previously defined—

cents 

CENTS/KVR—Never previously 

defined—cents per kilovolt amperes 

CENTS/KWH—Never previously 

defined—cents per kilowatt hour 

FLAT RATE—Never previously 

defined—rate not specified by any 

other units 

[FR Doc. E7–8640 Filed 5–7–07; 8:45 am] 

BILLING CODE 6717–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[FRL–8309–5] 

Issuance of Final NPDES General 

Permit for Groundwater Remediation 

Discharge Facilities in Idaho (Permit 

No. ID–G91–0000) 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notice of availability of final 

NPDES general permit. 

SUMMARY: The Director, Office of Water 

and Watersheds, EPA Region 10, is 

publishing notice of availability of a 

general National Pollutant Discharge 

Elimination System (NPDES) permit for 

groundwater remediation discharge 


cprice-sewell on PROD1PC66 with NOTICES