1876 Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 

(866) 208–3676 (toll free). For TTY, call 

(202) 502–8659. 

Comment Date: 5 p.m. Eastern Time 

on January 22, 2008. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. E8–235 Filed 1–9–08; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. EL08–22–000] 

Missouri River Energy Services; 

Western Minnesota Municipal Power 

Agency; Notice of Filing 

December 31, 2007. 

Take notice that on December 20, 

2007, pursuant to Rule 207(a)(2) and 

Rule 2004 of the Rules of Practices and 

Procedure of the Federal Energy 

Regulatory Commission, 18 CFR 

385.207(a)(2) and 385.2004 (2006), 

Missouri River Energy Services (MRES) 

and Western Minnesota Municipal 

Power Agency (Western Minnesota) 

filed a petition for declaratory order 

permitting MRES and Western 

Minnesota to combine their financial 

information for purposes of the 

variances being sought by MRES to the 

Attachment O transmission formula 

under the Midwest Independent 

Transmission System Operator, Inc.’s 

Open Access Transmission and Energy 

Markets Tariff. MRES and Western 

Minnesota also submit an exemption of 

the application fee, pursuant to section 

381.108 of the Commission’s Rules and 

Regulations. 

Any person desiring to intervene or to 

protest this filing must file in 

accordance with Rules 211 and 214 of 

the Commission’s Rules of Practice and 

Procedure (18 CFR 385.211, 385.214). 

Protests will be considered by the 

Commission in determining the 

appropriate action to be taken, but will 

not serve to make protestants parties to 

the proceeding. Any person wishing to 

become a party must file a notice of 

intervention or motion to intervene, as 

appropriate. Such notices, motions, or 

protests must be filed on or before the 

comment date. On or before the 

comment date, it is not necessary to 

serve motions to intervene or protests 

on persons other than the Applicant. 

The Commission encourages 

electronic submission of protests and 

interventions in lieu of paper using the 

‘‘eFiling’’ link at http://www.ferc.gov. 

Persons unable to file electronically 

should submit an original and 14 copies 

of the protest or intervention to the 

Federal Energy Regulatory Commission, 

888 First Street, NE., Washington, DC 

20426. 

This filing is accessible on-line at 

http://www.ferc.gov, using the 

‘‘eLibrary’’ link and is available for 

review in the Commission’s Public 

Reference Room in Washington, DC. 

There is an ‘‘eSubscription’’ link on the 

Web site that enables subscribers to 

receive e-mail notification when a 

document is added to a subscribed 

docket(s). For assistance with any FERC 

Online service, please e-mail 

FERCOnlineSupport@ferc.gov, or call 

(866) 208–3676 (toll free). For TTY, call 

(202) 502–8659. 

Comment Date: 5 p.m. Eastern Time 

on January 22, 2008. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. E8–236 Filed 1–9–08; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. EL08–28–000] 

City of Pasadena, CA; Notice of Filing 

December 31, 2007. 

Take notice that on December 21, 

2007, the City of Pasadena, California, 

filed its third annual revision to its 

Transmission Revenue Balancing 

Account Adjustment, to become 

effective January 1, 2008. 

Any person desiring to intervene or to 

protest this filing must file in 

accordance with Rules 211 and 214 of 

the Commission’s Rules of Practice and 

Procedure (18 CFR 385.211, 385.214). 

Protests will be considered by the 

Commission in determining the 

appropriate action to be taken, but will 

not serve to make protestants parties to 

the proceeding. Any person wishing to 

become a party must file a notice of 

intervention or motion to intervene, as 

appropriate. Such notices, motions, or 

protests must be filed on or before the 

comment date. On or before the 

comment date, it is not necessary to 

serve motions to intervene or protests 

on persons other than the Applicant. 

The Commission encourages 

electronic submission of protests and 

interventions in lieu of paper using the 

‘‘eFiling’’ link at http://www.ferc.gov. 

Persons unable to file electronically 

should submit an original and 14 copies 

of the protest or intervention to the 

Federal Energy Regulatory Commission, 

888 First Street, NE., Washington, DC 

20426. 

This filing is accessible on-line at 

http://www.ferc.gov, using the 

‘‘eLibrary’’ link and is available for 

review in the Commission’s Public 

Reference Room in Washington, DC. 

There is an ‘‘eSubscription’’ link on the 

Web site that enables subscribers to 

receive e-mail notification when a 

document is added to a subscribed 

docket(s). For assistance with any FERC 

Online service, please e-mail 

FERCOnlineSupport@ferc.gov, or call 

(866) 208–3676 (toll free). For TTY, call 

(202) 502–8659. 

Comment Date: 5 p.m. Eastern Time 

on January 22, 2008. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. E8–230 Filed 1–9–08; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. RM01–8–007] 

Revised Public Utility Filing 

Requirements for Electric Quarterly 

Reports 

December 21, 2007. 

AGENCY: Federal Energy Regulatory 

Commission, Department of Energy. 

ACTION: Order No. 2001–H; Order on 

Rehearing and Clarification. 

SUMMARY: In this order, the Federal 

Energy Regulatory Commission 

(Commission) grants in part, and denies 

in part, rehearing and clarifies the 

information to be reported in the 

Electric Quarterly Report’s (EQR’S) 

fields for Contract Execution Date (Field 

No. 21), Contract Commencement Date 

(Field No. 22) and Rate Description 

(Field No. 37). In addition, the order 

corrects an error relating to Increment 

Name (Field Nos. 28 and 60). 

DATES: This order becomes effective 

upon issuance. The revised definitions 

adopted in this order shall be applied to 

EQR filings beginning with the Q1 2008 

EQR (due on April 30, 2008) and in 

subsequent EQR filings due thereafter. 

FOR FURTHER INFORMATION CONTACT: 

Michelle Veloso (Technical 

Information), Office of Enforcement, 

Federal Energy Regulatory Commission, 

888 First Street, NE., Washington, DC 

20426, (202) 502–8363. 

Gary D. Cohen (Legal Information), 

Office of the General Counsel, Federal 

Energy Regulatory Commission, 888 


yshivers on PROD1PC62 with NOTICES
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 1877 

1Revised Public Utility Filing Requirements for 

Electric Quarterly Reports, Order No. 2001–G, 120 

FERC ¶ 61,270 (Sep. 24, 2007), 72 FR 56735 (Oct. 

4, 2007). 

2 Id. 

3Revised Public Utility Filing Requirements for, 

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

¶ 31,127 (2002), reh’g denied, Order No. 2001–A, 

100 FERC ¶ 61,074, reconsideration and 

clarification denied, Order No. 2001–B, 100 FERC 

¶ 61,342, order directing filings, Order No. 2001–

C, 101 FERC ¶ 61,314 (2002), order directing filings, 

Order No. 2001–D, 102 FERC ( 61,334, order 

refining filing requirements, Order No. 2001–E, 105 

FERC ¶ 61,352 (2003), clarification order, Order No. 

2001–F, 106 FERC ¶ 61,060 (2004). 

4Examples cited in EQR Notice at P 3. 

5Notice Seeking Comments on Proposed Electric 

Quarterly Report Data Dictionary, FERC Stats. & 

Regs. ¶ 35,050 (2007), 72 FR 26091 (May 8, 2007). 

6 In developing the EQR, the Commission 

identified a number of key terms associated with 

the products and services offered under any given 

jurisdictional contract. These terms include: Class 

Continued 

First Street, NE., Washington, DC 20426, 

(202) 502–8321. 

SUPPLEMENTARY INFORMATION: 

Before Commissioners: Joseph T. 

Kelliher, Chairman; Suedeen G. Kelly, 

Marc Spitzer, Philip D. Moeller, and Jon 

Wellinghoff. 

1. On October 24, 2007, Edison 

Electric Institute (EEI) filed a request for 

rehearing or clarification in response to 

the Commission’s order adopting an 

Electric Quarterly Report (EQR) Data 

Dictionary.1 Order No. 2001–G collected 

in one document the definitions of 

certain terms and values used in filing 

EQR data (previously provided in 

Commission orders and in guidance 

materials posted at the Commission’s 

website) and issued formal definitions 

for fields that were previously 

undefined.2 In this order, the 

Commission grants in part, and denies 

in part, rehearing and clarifies the 

information to be reported in Contract 

Execution Date (Field No. 21), Contract 

Commencement Date (Field No. 22) and 

Rate Description (Field No. 37). In 

addition, we correct an error that we 

made in Order No. 2001–G relating to 

Increment Name (Field Nos. 28 and 60). 

I. Background 

2. On April 25, 2002, the Commission 

issued Order No. 2001, a Final Rule 

establishing revised public utility filing 

requirements.3 This rule revised the 

Commission’s filing requirements to 

require companies subject to the 

Commission’s regulations under section 

205 of the Federal Power Act to file 

quarterly reports that: (1) Provide data 

identifying the utility on whose behalf 

the report is being filed (ID Data); (2) 

summarize pertinent data about the 

utility’s currently effective contracts 

(Contract Data); and (3) summarize data 

about wholesale power sales the utility 

made during the reporting period 

(Transaction Data). The requirement to 

file EQRs replaced the requirement to 

file quarterly transaction reports 

summarizing a utility’s market-based 

rate transactions and sales agreements 

that conformed to the utility’s tariff. 

3. In Order No. 2001, the Commission 

also adopted a new section in its 

regulations, 18 CFR 35.10b, which 

requires that the EQRs are to be 

prepared in conformance with the 

Commission’s software and guidance 

posted and available from the 

Commission website. This obviates the 

need to revise section 35.10b to 

implement revisions to the software and 

guidance. Since the issuance of Order 

No. 2001, as need has arisen, the 

Commission has issued orders to resolve 

questions raised by EQR users and has 

directed Staff to issue additional 

guidance.4

4. On September 24, 2007, the 

Commission issued Order No. 2001–G, 

providing a data dictionary to clarify the 

information to be reported in EQR data. 

EEI filed a request for rehearing or 

clarification requesting clarification of a 

few specific items. In addition, on 

December 4, 2007, TransAlta filed 

comments alerting the Commission to a 

filing problem it was experiencing 

relating to Increment Name (Field Nos. 

28 and 60). The discussion below 

addresses EEI’s rehearing request and 

TransAlta’s comments. 

II. Discussion 

A. Field No. 21—Contract Execution 

Date 

5. The EQR Notice 5 proposed only a 

slight change to the Order No. 2001 

definition for Contract Execution Date: 

‘‘The date the contract was signed. If the 

parties signed on different dates, or 

there are contract amendments, use the 

most recent date signed.’’

6. In response to the EQR Notice, 

Reliant and EEI suggested that the 

Contract Execution Date should not 

change because of a minor amendment 

to the contract. Both commenters noted 

that, frequently, contract amendments 

are minor changes, such as changes in 

an address or in payment terms, that do 

not affect the key operational 

parameters of the agreement. 

7. Based on these comments, the 

Commission found in Order No. 2001–

G that the usefulness of the data may be 

increased with a single execution date 

for each contract across all periods. 

However, the order explained that, if 

there are material amendments to the 

contract, then the Contract Execution 

Date must be changed. 

8. In EEI’s request for rehearing, it 

argues that the Commission’s 

instruction that the Contract Execution 

Date must be changed when there are 

material amendments to the contract is 

confusing and burdensome. It suggests 

that the original execution date should 

be reported for the duration of the 

contract and argues that changes in the 

contract will be reflected in the 

descriptions of revised contract 

provisions, such as in the Rate (Field 

No. 34), Begin Date (Field No. 43) and 

End Date fields (Field No. 44). 

Commission Conclusion 

9. In Order No. 2001–G, the 

Commission agreed with EEI and 

Reliant that it need not change the 

Contract Execution Date each time there 

is a minor revision to the contract and, 

accordingly, modified the instructions 

on what information should be reported 

in this field. The Commission reduced 

the burden and confusion by clarifying 

that minor, non-material changes may 

be omitted for the purpose of identifying 

the Contract Execution Date. EEI argues 

that the Contract Execution Date should 

not be revised, even in instances where 

there has been a material amendment to 

the contract. 

10. The Commission recognizes the 

benefits of classifying a contractual 

relationship based on when it originated 

and will revise the definition of 

Contract Execution Date as EEI suggests 

to require companies to report the 

original date the contract was executed, 

without regard to any subsequent 

revisions to the contract. For the 

purposes of the EQR Data Dictionary, 

the definition will read: ‘‘The date the 

contract was signed. If the parties signed 

on different dates, use the most recent 

date signed.’’ However, this change will 

not be incorporated at the cost of 

obscuring information that would alert 

EQR users that key terms in the contract 

have been revised. Thus, the 

Commission will revise the definition of 

Contract Commencement Date as 

described below. 

B. Field No. 22—Contract 

Commencement Date 

11. In order to alert EQR users that a 

contract has been revised, the 

Commission will revise the definition of 

Contract Commencement Date to refer to 

the date that service commenced under 

the current terms and conditions of the 

contract. The Commission will further 

clarify that the terms deemed relevant 

for determining or changing the 

Contract Commencement Date are those 

that are reported in the Contract Data 

section of the EQR.6 Any amendment 


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1878 Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 

Name, Term Name, Increment Name, Increment 

Peaking Name, Increment Peaking Name, Product 

Type Name, Product Name, Rate (actual, maximum, 

minimum or description), and Time Zone. The 

Commission requires that Class Name, Term Name, 

Increment Name, Increment Peaking Name, Product 

Type Name, Product Name, and Time Zone be 

reported in the EQR for every product offered under 

every jurisdictional contract. Additionally, the 

Commission requires a definition of the rate for 

every product either as a Rate, a Rate Minimum, a 

Rate Maximum or a Rate Description. Finally, the 

Commission requires that companies report, when 

specified in the contract for a given product, 

Quantity, Units, Rate Units, Point of Receipt 

Control Area, Point of Receipt Specific Location, 

Point of Delivery Control Area, Point of Delivery 

Specific Location, Begin Date, and End Date. 

7Revised Public Utility Filing Requirements for 

Electric Quarterly Reports, 72 Fed. Reg. 26091 (May 

8, 2007), FERC Stats. & Regs. ¶ 35,050 (2007) (EQR 

Notice). 

8EQR Notice at P. 18. 9See, for example, Order No. 2001 at P. 95. 

that would cause a change in these 

required data elements would require a 

change in the Contract Commencement 

Date. 

12. The Commission recognizes EEI’s 

concern regarding potential 

inconsistency between the EQR and 

eTariff in identifying an original 

execution date. However, there is a very 

real public interest in identifying when 

key terms of the contract were 

determined. As market conditions 

change over time, it is imperative to be 

able to sort the deals that occurred years 

ago from those that were confirmed 

more recently. To better understand the 

market conditions at the time a contract 

was put in place, it is necessary to 

document the date that key terms were 

established. 

13. The Commission will define 

Contract Commencement Date as ‘‘The 

date the terms of the contract reported 

in the EQR were effective. If the terms 

reported in the Contract Data section of 

the EQR became effective or if service 

under those terms began on multiple 

dates (i.e.: due to an amendment), the 

date to be reported as the 

Commencement Date is the date when 

service began pursuant to the most 

recent amendment to the terms reported 

in the Contract Data section of the 

EQR.’’ In this way, the Commission and 

the public will continue to be able to 

determine when the contract terms 

reported in the EQR were determined. 

C. Field Nos. 28 and 60—Increment 

Name 

14. In the EQR Notice,7 the 

Commission proposed to revise Field 

Nos. 28 and 60 to, among other matters, 

create an Increment Name covering 

‘‘Seasonal’’ sales to characterize power 

sales made for longer than one month, 

but less than a year.8 This proposal was 

opposed in comments filed by EEI, 

Reliant and Occidental. In Order No. 

2001–G, the Commission agreed with 

the commenters that the term ‘‘S—

Seasonal’’ should not be included in the 

options available for the Increment 

Name fields. However, in the issued 

Order No. 2001–G, when the term 

‘‘Seasonal’’ was dropped from the Data 

Dictionary, the interval to be included 

in ‘‘Monthly’’ should have been 

adjusted in the attached Data 

Dictionary, so there would be no gap 

between ‘‘Monthly’’ and ‘‘Annual.’’

Unfortunately, this correction was 

inadvertently omitted. 

15. On December 4, 2007, TransAlta 

filed comments alerting the Commission 

to this problem. 

Commission Conclusion 

16. We will take this opportunity to 

correct the inadvertent error in Order 

No. 2001–G involving Increment Name, 

so that filers can accurately report their 

sales covering a period of more than 168 

consecutive hours up to one year as MMonthly (>168 consecutive hours and < 

1 year). 

D. Field No. 37—Rate Description 

17. The EQR Notice proposed 

defining Rate Description as a ‘‘[t]ext 

description of rate. May reference FERC 

tariff, or, if a discounted or negotiated 

rate, include algorithm.’’ EEI filed 

comments in response to the EQR 

Notice requesting that filers be allowed 

to enter the tariff location into the Rate 

Description field in lieu of a detailed 

description of the rate itself. EEI 

supported this request by citing the 

difficulty of putting complex rates into 

the 150 character field. In Order No. 

2001–G, the Commission stated that the 

EQR fulfills the Commission’s statutory 

obligation under the Federal Power Act 

(FPA) to have companies’ rates on file. 

We further stated that the Commission 

relies on the EQR to satisfy the FPA 

requirement that rates provided in a 

contract be publicly disclosed and on 

file. Thus, we concluded that it is 

imperative that the information reported 

in EQRs provide an adequate level of 

detail and transparency. 

18. The Commission also stated in 

Order No. 2001–G that a tariff reference 

alone, instead of the actual rate 

description, does not meet the FPA 

standard. Allowing filers to substitute a 

tariff reference in place of an actual rate 

description would force EQR users 

seeking this information to conduct 

further research to track down the 

contents of the tariff on file. This is 

clearly less transparent than a rate 

description that actually describes the 

rate. We also explained that, if the tariff 

reference is coupled with a descriptive 

summary of the rate, where the rate is 

the function of a complex algorithm, the 

standard is met. Further, we explained 

that rate information will continue to be 

available to the public at a level 

sufficient to explain the bases and 

methods of calculation with additional 

detail available upon request to 

interested persons. 

19. On rehearing, EEI argues that, in 

the case of cost-based rates, the FPA 

requirement that rates be on file is 

satisfied by separate on-the-record 

Commission filings, so it is not 

necessary to provide a rate description 

in the EQR to satisfy the FPA. Thus, it 

argues, a reference to the rate schedule 

number and page is sufficient for EQR 

purposes, without any text description 

of the rate. 

Commission Conclusion 

20. Prior to the adoption of Order No. 

2001, public utilities satisfied the FPA 

requirement to have their rates on file 

with the Commission without filing 

EQRs (which had not yet been 

established). Thus, EEI is correct that 

the EQR filings are not the sole means 

by which this legal requirement can be 

met. However, section 205(c) provides 

the Commission with wide discretion 

on how companies are to file their rates 

and, in Order No. 2001, the Commission 

established the EQR as a means to 

ensure compliance with the FPA, and to 

provide a mechanism for the public to 

inspect and review the pertinent terms 

and conditions of public utilities’

contracts and transactions in an 

electronic format that afforded greater 

transparency and accessibility to this 

information.9

21. When this issue first was 

considered in Order No. 2001–G, it 

centered on the question of whether 150 

characters would be sufficient to 

provide all the information needed to 

accurately describe a public utility’s 

rates. After consideration of EEI’s 

arguments and the problem of fitting an 

accurate rate description into 150 

characters without sacrificing 

transparency, we are persuaded to 

revise the definition for Rate 

Description to include a provision that 

relates to a rate that is currently on file 

with the Commission. The Commission 

will define Rate Description as ‘‘[t]ext 

description of rate. If the rate is 

currently available on the FERC Web 

site, a citation of the FERC Accession 

Number and the relevant FERC tariff 

including page number or section may 

be included instead of providing the 

entire rate algorithm. If the rate is not 

available on the FERC Web site, include 

the rate algorithm, if rate is calculated. 


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Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 1879 

If the algorithm would exceed the 150 

character field limit, it may be provided 

in a descriptive summary (including 

bases and methods of calculations) with 

a detailed citation of the relevant FERC 

tariff including page number and 

section. If more than 150 characters are 

required, the contract product may be 

repeated in subsequent lines of data 

until the rate is adequately described.’’

With this revision of Rate Description, 

EQR filers may provide the necessary 

information without sacrificing 

transparency. 

III. Document Availability 

22. In addition to publishing the full 

text of this document in the Federal 

Register, the Commission provides all 

interested persons an opportunity to 

view and/or print the contents of this 

document via the Internet through the 

Commission’s Home Page (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. 

23. From the Commission’s Home 

Page on the Internet, this information is 

available in the eLibrary. The full text 

of this document is available in the 

eLibrary both in PDF and Microsoft 

Word format for viewing, printing, and/ 

or downloading. To access this 

document in eLibrary, type ‘‘RM01–8’’

in the docket number field. User 

assistance is available for eLibrary and 

the Commission’s website during the 

Commission’s normal business hours. 

For assistance contact the Commission’s 

Online Support services at 

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

contact (202) 502–8659. 

The Commission orders: 

(A) EEI’s request for rehearing or 

clarification is hereby granted in part, 

and denied in part, as discussed in the 

body of this order. 

(B) TransAlta’s request for 

clarification is hereby granted, as 

discussed in the body of this order. 

(C) The revised definitions adopted in 

this order shall be applied to EQR 

filings beginning with the Q1 2008 EQR 

(due on April 30, 2008) and in 

subsequent EQR filings due thereafter. 

By the Commission. 

Kimberly D. Bose, 

Secretary. 

Attachment 

Electric Quarterly Report Data 

Dictionary Version 1.0 (Issued —) 

EQR DATA DICTIONARY

Field 

No. Field Required Value Definition 

ID Data 

1 .......... Filer Unique 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 commadelimited (csv) file that is imported into the EQR filing. One 

record for each seller company may be imported into an EQR 

for a given quarter. 

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 

(100 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 

(100 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 

(100 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. 


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1880 Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 

EQR DATA DICTIONARY—Continued 

Field 

No. Field Required Value Definition 

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). 

Contract Data 

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 

(100 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. 

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, power sales or sales of related jurisdictional 

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

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

order granting the Seller Market Based Rate Authority must be 

listed. 

20 ........ Contract Service 

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, use the most recent date signed. 

22 ........ Contract Commencement Date.✓ ............................ YYYYMMDD .......... The date the terms of the contract reported in the EQR were effective. If the terms reported in the Contract Data section of the 

EQR became effective or if service under those terms began on 

multiple dates (i.e.: due to an amendment), the date to be reported as the Commencement Date is the date when service 

began pursuant to the most recent amendment to the terms reported in the Contract Data section of the EQR. 

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, a service or product that always has priority over non-firm service. For power sales, a service or product 

that is not interruptible for economic reasons. 


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EQR DATA DICTIONARY—Continued 

Field 

No. Field Required Value Definition 

26 ........ Class Name ........... ✓ ............................ NF—Non-firm ......... For transmission sales, a service that is reserved and/or scheduled on an as-available basis and is subject to curtailment or 

interruption at a lesser priority compared to Firm service. For an 

energy sale, a service or product for which delivery or receipt of 

the energy may be interrupted for any reason or no reason, 

without liability on the part of either the buyer or seller. 

26 ........ Class Name ........... ✓ ............................ UP—Unit Power 

Sale.

Designates a dedicated sale of energy and capacity from one or 

more than one specified generation unit(s). 

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

apply. 

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 60 consecutive hours (> 6 and ≤ 60 consecutive hours). 

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

over 60 consecutive hours and up to 168 consecutive hours 

(> 60 and ≤ 168 consecutive hours). 

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

more than 168 consecutive hours up to, but not including, one 

year (> 168 consecutive hours and < 1 year). 

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

one year or more (≥ 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 those hours designated 

as on-peak and off-peak in the NERC region of the point of delivery. 

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 ✓ ............................ CR—Capacity Reassignment.An agreement under which a transmission provider sells, assigns 

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

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

Maximum rate to be charged per the contract, if a range is specified. 

36 ........ Rate Maximum ...... ................................ Number with up to 

4 decimals.

Maximum rate to be charged per the contract, if a range is specified. 


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EQR DATA DICTIONARY—Continued 

Field 

No. Field Required Value Definition 

37 ........ Rate Description .... Unrestricted text ..... Text description of rate. If the rate is currently available on the 

FERC Web site, a citation of the FERC Accession Number and 

the relevant FERC tariff including page number or section may 

be included instead of providing the entire rate algorithm. If the 

rate is not available on the FERC Web site, include the rate algorithm, if rate is calculated. If the algorithm would exceed the 

150 character field limit, it may be provided in a descriptive summary (including bases and methods of calculations) with a detailed citation of the relevant FERC tariff including page number 

and section. If more than 150 characters are required, the contract product may be repeated in a subsequent line of data until 

the rate is adequately described. 

38 ........ Rate Units .............. If specified in the 

contract.

See Rate Units 

Table, Appendix 

F.

Measure stated in the contract for the product sold. 

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) where service begins for a transmission or transmission-related jurisdictional sale. The Balancing Authority will 

be identified with the abbreviation used in OASIS applications. If 

receipt occurs at a trading hub specified in the EQR software, 

the term ‘‘Hub’’ should be used. 

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

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. If more points of receipt are listed in 

the contract than can fit into the 50 character space, a description of the collection of points may be used. ‘Various,’ alone, is 

unacceptable unless the contract itself uses that terminology. 

41 ........ Point of Delivery 

Balancing Authority (PODBA).

If specified in the 

contract.

See Balancing Authority Table, Appendix B.The registered NERC Balancing Authority (formerly called NERC 

Control Area) where a jurisdictional product is delivered and/or 

service ends for a transmission or transmission-related jurisdictional sale. The Balancing Authority will be identified with the abbreviation used in OASIS applications. If delivery occurs at the 

interconnection of two control areas, the control area that the 

product is entering should be used. If delivery occurs at a trading hub specified in the EQR software, the term ‘‘Hub’’ should 

be used. 

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. 

Transaction Data 

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 

(100 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. 

49 ........ Customer DUNS 

Number.

✓ ............................ Nine digit number .. The unique nine digit number assigned by Dun and Bradstreet to 

the counterparty to the contract. 


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EQR DATA DICTIONARY—Continued 

Field 

No. Field Required Value Definition 

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, power sales or sales of related jurisdictional 

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

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

order granting the Seller Market Based Rate Authority must be 

listed. 

51 ........ Contract Service 

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).

MMDDYYYYHHMM 

(manual entry).

First date and time the product is sold during the quarter. 

54 ........ Transaction End 

Date.

✓ ............................ YYYYMMDDHHMM 

(csv import).

MMDDYYYYHHMM 

(manual entry).

Last date and time the product is sold during the quarter. 

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 .................. A sale, service or product that is not interruptible for economic reasons. 

58 ........ Class Name ........... ✓ ............................ NF—Non-firm ......... A sale for which delivery or receipt of the energy may be interrupted for any reason or no reason, without liability on the part 

of either the buyer or seller. 

58 ........ Class Name ........... ✓ ............................ UP—Unit Power 

Sale.

Designates a dedicated sale of energy and capacity from one or 

more than one specified generation unit(s). 

58 ........ Class Name ........... ✓ ............................ BA—Billing Adjustment.Designates an incremental material change to one or more transactions due to a change in settlement results. ‘‘BA’’ may be 

used in a refiling after the next quarter’s filing is due to reflect 

the receipt of new information. It may not be used to correct an 

inaccurate filing. 

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 60 consecutive hours (> 6 and ≤ 60 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 60 consecutive hours and 

up to 168 consecutive hours (> 60 and ≤ 168 consecutive 

hours). Includes sales for a full week and sales for peak and offpeak blocks over a particular week. 

60 ........ Increment Name .... ✓ ............................ M—Monthly ............ Terms of the particular sale set for set for more than 168 consecutive hours up to, but not including, one year (>168 consecutive 

hours and < 1 year). Includes sales for full month or multi-week 

sales during a given month. 


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EQR DATA DICTIONARY—Continued 

Field 

No. Field Required Value Definition 

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 (fixedprice, formula, or index). 

60 ........ Increment Name .... ✓ ............................ DN/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 was sold during Peak and Off-Peak hours. 

61 ........ Increment Peaking 

Name.

✓ ............................ OP—Off-Peak ........ The product described was 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 was 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. 

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.

Actual price charged for the product per unit. The price reported 

cannot be averaged or otherwise aggregated. 

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. 

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 ................................................. ✓ ✓ Transaction whereby the receiver accepts delivery of energy for 

a supplier’s account and returns energy at times, rates, and in 

amounts as mutually agreed if the receiver is not an RTO/ 

ISO. 

FUEL CHARGE ........................................... ✓ ✓ 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. 


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EQR DATA DICTIONARY—APPENDIX A. PRODUCT NAMES—Continued 

Product name Contract 

product 

Transaction 

product Definition 

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). 

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 Outside US * 

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 ........................


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EQR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued 

Balancing authority Abbreviation Outside US * 

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

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

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

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

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

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

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

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

British Columbia Transmission Corporation .............................................................................................................. BCTC ✓ 

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 ........................

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, AR ........................................................................ 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 ........................

Manitoba Hydro Electric Board, Transmission Services ........................................................................................... MHEB ✓ 

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


yshivers on PROD1PC62 with NOTICES
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 1887 

EQR DATA DICTIONARY—APPENDIX B. BALANCING AUTHORITY—Continued 

Balancing authority Abbreviation Outside US * 

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 ........................

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 ........................

* Balancing authorities outside the United States may only be used in the Contract Data section to identify specified receipt/delivery points in 

jurisdictional transmission contracts. 


yshivers on PROD1PC62 with NOTICES
1888 Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 

EQR DATA DICTIONARY—APPENDIX C. HUB

HUB Definition 

ADHUB ........................... The aggregated Locational Marginal Price (‘‘LMP’’) nodes defined by PJM Interconnection, LLC as the AEP/Dayton 

Hub. 

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 border 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). 

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

Entergy balancing authority. 

FE Hub ............................ The aggregated Elemental Pricing nodes (‘‘Epnodes’’) 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. Palo Verde Hub includes the 

Hassayampa switchyard 2 miles south of Palo Verde. 

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

Southern Company balancing authority. 

SP15 ............................... The set of delivery points south of Path 15 on the California transmission grid commonly identified as and agreed to 

by the counterparties to constitute the SP15 Hub. 

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

Tennessee Valley Authority balancing authority. 

ZP26 ............................... The set of delivery points associated with Path 26 on the California transmission grid commonly identified as and 

agreed to by the counterparties to constitute the ZP26 Hub. 

EQR DATA DICTIONARY—APPENDIX D. 

TIME ZONE

Time zone Definition 

AD ........................ Atlantic Daylight. 

AP ........................ Atlantic Prevailing. 

AS ........................ Atlantic Standard. 

CD ........................ Central Daylight. 

CP ........................ Central Prevailing. 

CS ........................ Central Standard. 

ED ........................ Eastern Daylight. 

EP ........................ Eastern Prevailing. 

ES ........................ Eastern Standard. 

MD ........................ Mountain Daylight. 

MP ........................ Mountain Prevailing. 

MS ........................ Mountain Standard. 

NA ........................ Not Applicable. 

PD ........................ Pacific Daylight. 

EQR DATA DICTIONARY—APPENDIX D. 

TIME ZONE—Continued 

Time zone Definition 

PP ........................ Pacific Prevailing. 

PS ........................ Pacific Standard. 

UT ........................ Universal Time. 

EQR DATA DICTIONARY—APPENDIX E. 

UNITS

Units Definition 

KV ............... Kilovolt. 

KVA ............ Kilovolt Amperes. 

KVR ............ Kilovar. 

KW .............. Kilowatt. 

EQR DATA DICTIONARY—APPENDIX E. 

UNITS—Continued 

Units Definition 

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. 


yshivers on PROD1PC62 with NOTICES
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Notices 1889 

EQR DATA DICTIONARY—APPENDIX F. 

RATE UNITS

Rate units Definition 

$/KV .................. dollars per kilovolt. 

$/KVA ............... dollars per kilovolt amperes. 

$/KVR ............... dollars per kilovar. 

$/KW ................. dollars per kilowatt. 

$/KWH .............. dollars per kilowatt hour. 

$/KW–DAY ....... dollars per kilowatt day. 

$/KW–MO ......... dollars per kilowatt month. 

$/KW–WK ......... dollars per kilowatt week. 

$/KW–YR .......... dollars per kilowatt year. 

$/MW ................ dollars per megawatt. 

$/MWH .............. dollars per megawatt hour. 

$/MW–DAY ....... dollars per megawatt day. 

$/MW–MO ........ dollars per megawatt 

month. 

$/MW–WK ........ dollars per megawatt 

week. 

$/MW–YR ......... dollars per megawatt year. 

$/MVAR–YR ..... dollars per megavar year. 

$/RKVA ............. dollars per reactive kilovar 

amperes. 

CENTS ............. cents. 

CENTS/KVR ..... cents per kilovolt amperes. 

CENTS/KWH .... cents per kilowatt hour. 

FLAT RATE ...... rate not specified in any 

other units. 

[FR Doc. E8–184 Filed 1–9–08; 8:45 am] 

BILLING CODE 6717–01–P 

FEDERAL HOUSING FINANCE BOARD 

Sunshine Act Meeting Notice; 

Announcing a Partially Open Meeting 

of the Board of Directors 

TIME AND DATE: The open meeting of the 

Board of Directors is scheduled to begin 

at 10 am on Tuesday, January 15, 2008. 

The closed portion of the meeting will 

follow immediately the open portion of 

the meeting. 

PLACE: Board Room, First Floor, Federal 

Housing Finance Board, 1625 Eye 

Street, NW., Washington, DC 20006. 

STATUS: The first portion of the meeting 

will be open to the public. The final 

portion of the meeting will be closed to 

the public. 

MATTER TO BE CONSIDERED AT THE OPEN

PORTION: Federal Home Loan Bank of 

San Francisco—Waiver of Certain AHP 

Regulations to Permit Refinancing/ 

Modification of Subprime Mortgage 

Loans. 

MATTER TO BE CONSIDERED AT THE CLOSED

PORTION: Periodic Update of 

Examination Program Development and 

Supervisory Findings. 

CONTACT PERSON FOR MORE INFORMATION: 

Shelia Willis, Paralegal Specialist, 

Office of General Counsel, at 202–408–

2876 or williss@fhfb.gov. 

Dated: January 8, 2008. 

By the Federal Housing Finance Board. 

Neil R. Crowley, 

Acting General Counsel. 

[FR Doc. 08–85 Filed 1–8–08; 3:59 pm] 

BILLING CODE 6725–01–P 

FEDERAL RESERVE SYSTEM 

Formations of, Acquisitions by, and 

Mergers of Bank Holding Companies 

The companies listed in this notice 

have applied to the Board for approval, 

pursuant to the Bank Holding Company 

Act of 1956 (12 U.S.C. 1841 et seq.) 

(BHC Act), Regulation Y (12 CFR Part 

225), and all other applicable statutes 

and regulations to become a bank 

holding company and/or to acquire the 

assets or the ownership of, control of, or 

the power to vote shares of a bank or 

bank holding company and all of the 

banks and nonbanking companies 

owned by the bank holding company, 

including the companies listed below. 

The applications listed below, as well 

as other related filings required by the 

Board, are available for immediate 

inspection at the Federal Reserve Bank 

indicated. The application also will be 

available for inspection at the offices of 

the Board of Governors. Interested 

persons may express their views in 

writing on the standards enumerated in 

the BHC Act (12 U.S.C. 1842(c)). If the 

proposal also involves the acquisition of 

a nonbanking company, the review also 

includes whether the acquisition of the 

nonbanking company complies with the 

standards in section 4 of the BHC Act 

(12 U.S.C. 1843). Unless otherwise 

noted, nonbanking activities will be 

conducted throughout the United States. 

Additional information on all bank 

holding companies may be obtained 

from the National Information Center 

Web site at www.ffiec.gov/nic/. 

Unless otherwise noted, comments 

regarding each of these applications 

must be received at the Reserve Bank 

indicated or the offices of the Board of 

Governors not later than February 5, 

2008. 

A. Federal Reserve Bank of Kansas 

City (Todd Offerbacker, Assistant Vice 

President) 925 Grand Avenue, Kansas 

City, Missouri 64198–0001: 

1. Young Partners, L.P., and its 

general partner, Young Corporation, 

and Citizens Bancshares Company, all 

of Chillicothe, Missouri, and First 

Community Bancshares, Inc., and FCB 

Acquisition Corp., both of Overland 

Park, Kansas; to acquire NKC 

Bancshares, Inc., and thereby indirectly 

acquire Norbank, both of North Kansas 

City, Missouri. In connection with this 

application, FCB Acquisition Corp, has 

applied to become a bank holding 

company by merging with NKC 

Bancshares Inc. 

Board of Governors of the Federal Reserve 

System, January 7, 2008. 

Robert deV. Frierson, 

Deputy Secretary of the Board. 

[FR Doc. E8–262 Filed 1–9–08; 8:45 am] 

BILLING CODE 6210–01–S 

DEPARTMENT OF HEALTH AND 

HUMAN SERVICES 

Centers for Disease Control and 

Prevention 

[60Day–08–0008] 

Proposed Data Collections Submitted 

for Public Comment and 

Recommendations 

In compliance with the requirement 

of section 3506(c)(2)(A) of the 

Paperwork Reduction Act of 1995 for 

opportunity for public comment on 

proposed data collection projects, the 

Centers for Disease Control and 

Prevention (CDC) will publish periodic 

summaries of proposed projects. To 

request more information on the 

proposed projects or to obtain a copy of 

the data collection plans and 

instruments, call 404–639–5960 and 

send comments to Maryam I. Daneshvar, 

CDC Acting Reports Clearance Officer, 

1600 Clifton Road, MS–D74, Atlanta, 

GA 30333 or send an e-mail to 

omb@cdc.gov. 

Comments are invited on: (a) Whether 

the proposed collection of information 

is necessary for the proper performance 

of the functions of the agency, including 

whether the information shall have 

practical utility; (b) the accuracy of the 

agency’s estimate of the burden of the 

proposed collection of information; (c) 

ways to enhance the quality, utility, and 

clarity of the information to be 

collected; and (d) ways to minimize the 

burden of the collection of information 

on respondents, including through the 

use of automated collection techniques 

or other forms of information 

technology. Written comments should 

be received within 60 days of this 

notice. 

Proposed Project 

Hazardous Substances Emergency 

Events Surveillance (HSEES)—

Extension—(0923–0008), Agency for 

Toxic Substances and Disease Registry 

(ATSDR), Centers for Disease Control 

and Prevention (CDC). 

Background and Brief Description 

The Agency for Toxic Substances and 

Disease Registry (ATSDR) is mandated 


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