124 FERC ¶ 61,273 

UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

18 CFR Parts 41 and 141 

Docket No. RM08-5-000; Order No. 715 

Revisions to Forms, Statements and Reporting Requirements for 

Electric Utilities and Licensees 

(Issued September 19, 2008) 

 

AGENCY: Federal Energy Regulatory Commission. 

ACTION: Final Rule. 

SUMMARY: This Final Rule amends the Federal Energy Regulatory Commission’s 

reporting requirements for public utilities and licensees to file financial forms, reports, 

and statements, including FERC Form No. 1, FERC Form No. 1-F, and FERC Form No. 

3-Q. These changes will improve the forms, reports and statements to provide, in fuller 

detail, the information the Commission needs to carry out its responsibilities under the 

Federal Power Act to ensure that rates remain just and reasonable. In addition, the 

changes will help provide public utility customers, state commissions, and the public 

information to assess the justness and reasonableness of electric rates. 

EFFECTIVE DATE: This rule will become effective January 1, 2009. 

FOR FURTHER INFORMATION CONTACT: 

David Lengenfelder (Technical Information) 

Forms Administration and Data Branch, Division of Financial Regulation 

Office of Enforcement 

Federal Energy Regulatory Commission 

888 First Street, N.E., Washington, D.C. 20426 

Telephone: (202) 502-8351, e-mail: david.lengenfelder@ferc.gov 
Docket No. RM08-5-000 - 2 - 

Richard M. Wartchow (Legal Information) 

Office of the General Counsel 

Federal Energy Regulatory Commission 

888 First Street, N.E., Washington, D.C. 20426 

Telephone: (202) 502-8744, e-mail: richard.wartchow@ferc.gov 

SUPPLEMENTARY INFORMATION:
UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

Revisions to Forms, Statements and Reporting 

Requirements for Electric Utilities and Licensees 

Docket No. RM08-5-000 

18 CFR Parts 41 and 141 

ORDER NO. 715 

FINAL RULE

 Paragraph Numbers

I. Introduction .................................................................................................................... 1.

II. Background................................................................................................................... 6.

III. Notice of Inquiry ....................................................................................................... 10.

IV. Notice of Proposed Rulemaking ............................................................................... 11.

V. Discussion................................................................................................................... 12.

A. Notice of Inquiry .................................................................................................... 12.

B. Notice of Proposed Rulemaking............................................................................. 13.

C. Effective Date ........................................................................................................ 19.

D. Proposed Revisions ................................................................................................ 21.

1. Formula Rates..................................................................................................... 21.

2. Filing Thresholds for Form 1 ............................................................................. 51.

3. Affiliate Transactions ......................................................................................... 56.

4. CPA Certification for a Non-Calendar Fiscal Year ........................................... 74.

5. “Other Revenues” (Pages 300-301).................................................................... 78.

6. Increases to Threshold Reporting Levels .......................................................... 91.

7. Proposed Technical Corrections......................................................................... 94.

8. Additional Technical Revisions.......................................................................... 98.

E. Miscellaneous ....................................................................................................... 103.

1. Retaining Form 3-Q.......................................................................................... 103.

2. Confidentiality Concerns.................................................................................. 107.

3. Requests to Reconsider Rejected Revisions..................................................... 111.

4. Requests for Additional Cost Data ................................................................... 116.

F. Reporting Burden ................................................................................................. 121.

VI. Information Collection Statement ........................................................................... 129.

VII. Environmental Analysis......................................................................................... 130.

VIII. Regulatory Flexibility Act.................................................................................... 131.
Docket No. RM08-5-000 ii 

IX. Document Availability ............................................................................................ 132.

X. Effective Date and Congressional Notification........................................................ 135.

Revised Regulatory Text — 18 CFR Parts 41 and 141. 

Appendix A: Revised Form 1 Pages. 

Appendix B: List of Proposed Technical Changes and Responses. 

Appendix C: List of Commenters. 
UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

Before Commissioners: Joseph T. Kelliher, Chairman; 

 Suedeen G. Kelly, Marc Spitzer, 

 Philip D. Moeller, and Jon Wellinghoff. 

Revisions to Forms, Statements and Reporting 

Requirements for Electric Utilities and Licensees 

Docket No. RM08-5-000 

FINAL RULE 

ORDER NO. 715 

(Issued September 19, 2008) 

I. Introduction

1. This Final Rule amends the Federal Energy Regulatory Commission’s 

(Commission) reporting requirements for public utilities1

 and licensees to file financial 

forms, reports, and statements, including FERC Form No. 1 (Form 1), FERC Form No. 1-

F (Form 1-F), and FERC Form No. 3-Q (Form 3-Q). These changes will improve the 

forms, reports and statements to provide, in fuller detail, the information the Commission 

needs to carry out its responsibilities under the Federal Power Act (FPA) to ensure that 

rates remain just and reasonable. In addition, the changes will help provide public utility 

 1

 While 18 CFR 141.1 nominally refers to “electric utilities,” this regulation in fact 

applies to “public utilities.” See 16 U.S.C. 824; accord 18 CFR Part 101, Definitions 29 

and 40. The reference in 18 CFR 141.1 to “electric utilities” predates the 1978 addition 

of separate statutorily defined “electric utilities,” see 16 U.S.C. 796(22), when the only 

utilities that were Commission regulated under the Federal Power Act were the 

statutorily-defined public utilities, see 16 U.S.C. 824. See, e.g., 18 CFR 141.1 (1977). 
Docket No. RM08-5-000 - 2 - 

customers, state commissions, and the public the information they need to assess the 

justness and reasonableness of electric rates. 

2. This Final Rule complements the Commission’s recent revisions to the reporting 

requirements for natural gas companies;2

 it revises the financial forms filed by public 

utilities and licensees — specifically, Form 1, Annual report for major electric utilities, 

licensees, and others; Form 1-F, Annual report for nonmajor public utilities, licensees and 

others; and Form 3-Q, Quarterly report of electric utilities, licensees, and natural gas 

companies. 

3. Specifically, the Final Rule adopts revised reporting requirements which will 

enhance the Commission’s and customers’ review of formula rates; permit better 

understanding of non-power goods and services transactions with affiliates, and provide 

additional detail of revenues not previously specified in Form 1. In addition, the Final 

Rule will expedite reporting by clarifying Form 1 instructions and cross-references and 

making certain technical improvements in the form. Finally, the Final Rule responds to 

the burdens faced by filers by adopting minimum reporting thresholds for certain 

accounting data, eliminating the reporting requirement for certain utilities that are not 

otherwise subject to this Commission’s reporting obligations or jurisdiction, and 

 2

 18 CFR Parts 158 and 260; Revisions to Forms, Statements, and Reporting 

Requirements for Natural Gas Pipelines, Order No. 710, Docket No. RM07-9-000, 73 FR 

19389 (Apr. 10, 2008), FERC Stats. & Regs. ¶ 31,267, order on reh’g, Order No. 710-A, 

123 FERC ¶ 61,278 (2008). 
Docket No. RM08-5-000 - 3 - 

accommodating filers whose fiscal year does not fall in the calendar year that is used for 

reporting purposes. 

4. This Final Rule does not convert the submission of Form 1 and other data into a 

FPA section 2053

 rate case filing or a cost-and-revenue study, but is instead intended to 

better ensure a ready source of data to assist the Commission and interested parties in 

evaluating the justness and reasonableness of a utility’s rates. The revised forms do not 

limit or change an entity’s rights or obligations under the FPA and our regulations, and 

this Final Rule is not intended to change our obligation to rule on complaints, petitions, 

or other requests for relief based on a full record and substantial evidence. 

5. The proposed effective date for implementation of these changes is calendar year 

2009. Accordingly, companies subject to the new requirements would file their new 

Form 3-Qs following the first calendar quarter of 2009 and their new Forms 1 and 1-F in 

April 2010 for calendar year 2009. In addition, this Final Rule eliminates the filing 

requirement for utilities not subject to the Commission’s jurisdiction under section 201 of 

the FPA4

 but required to file Form 1 solely because they met the reporting threshold in 

the regulations. 

 3

 16 U.S.C. 824d. 

4

 16 U.S.C. 824. 
Docket No. RM08-5-000 - 4 - 

II. Background

6. Under the Commission’s regulations, entities classified as major electric utilities 

are required to file Form 1. Entities classified as nonmajor electric utilities are required 

to file Form 1-F.5

 Sections 304, 307 and 309 of the FPA authorize the Commission to 

collect such data.6

 Form 1, in particular, requires information to be filed on an annual 

basis by public utilities (and certain hydroelectric production sources) under the 

Commission’s jurisdiction. Form 1 collects corporate information, summary financial 

information and balance sheet and income information, as well as electric plant, sales, 

operating and statistical data. Since its inception, Form 1 has been amended by the 

Commission on numerous occasions to address and keep pace with the transformation of 

the utility industry. 

7. In 1990, the Commission issued Order No. 529, which modified Form 1 to 

improve reporting of bulk power transactions.7

 In 1993, the Commission issued Order 

 5

 A major electric utility is one that had, in the last three consecutive years, sales 

or transmission services that exceeded (1) one million megawatt-hours of total sales; 

(2) 100 megawatt-hours of sales for resale; (3) 500 megawatt-hours of power exchanges 

delivered; or (4) 500 megawatt-hours of wheeling for others (deliveries plus losses). 

Utilities and licensees that are not classified as major and had total sales in each of the 

last three consecutive years of 10,000 megawatt-hours or more are classified as 

nonnmajor. See 18 CFR Part 101. 

6

 16 U.S.C. 825a, 825f, 825h; see also 16 U.S.C. 825j. 

7

 Amendments to FERC Form Nos. 1 and 1-F, and Annual Charges, and Fuel Cost 

and Purchased Economic Power Adjustment Clauses, Order No. 529, FERC Stats. & 

Regs. ¶ 30,904 (1990). 
Docket No. RM08-5-000 - 5 - 

No. 552, which revised the Uniform System of Accounts (USofA) to account for 

allowances under the 1990 Clean Air Act Amendments, and adopted corresponding 

reporting schedules for Forms 1 and 1-F.8

 

8. In 1994, the Commission issued Order No. 574, which required the filing of an 

electronic version of Form 1, along with the paper version. The electronic version was 

prepared pursuant to a computer program supplied by the Commission.9

 In 2002, the 

Commission issued Order No. 626, which eliminated the paper filing requirement, 

relying solely on electronic filing of Form 1.10 Also in 2002, the Commission expanded 

USofA accounting requirements to include monitoring for the fair value of certain 

security investments, derivative instruments, and hedging activities, and added new 

schedules and accounts to Forms 1 and 1-F.11 

 8

 Revisions to Uniform System of Accounts to Account for Allowances under the 

Clean Air Act Amendments of 1990 and Regulatory-Created Assets and Liabilities and to 

Form Nos. 1, 1-F, 2 and 2-A, Order No. 552, FERC Stats. & Regs. ¶ 30,967 (1993). 

9

 Electronic Filing of FERC Form No. 1 and Delegation to Chief Accountant, 

Order No. 574, FERC Stats. & Regs. ¶ 31,013 (1994) (establishing the Form 1 

Submission Software (FOSS)). 

10 Electronic Filing of FERC Form No. 1, and Elimination of Certain Designated 

Schedules in Form Nos. 1 and 1-F, Order No. 626, FERC Stats. & Regs. ¶ 31,130 (2002). 

11 Accounting and Reporting of Financial Instruments, Comprehensive Income, 

Derivatives and Hedging Activities, Order No. 627, FERC Stats. & Regs. ¶ 31,134 

(2002). 
Docket No. RM08-5-000 - 6 - 

9. Order No. 646 implemented quarterly reporting for entities that filed Forms 1 and 

1-F and added annual reporting requirements for ancillary services and electric 

transmission peak loads.12 In 2005, Order No. 668 updated the Commission’s accounting 

requirements for utilities and licensees, including independent system operators (ISOs) 

and regional transmission organizations (RTOs).13 The Commission also revised its 

USofA and Forms 1 and 1-F to accommodate industry restructuring under the 

Commission’s open-access transmission policies and increased competition in wholesale 

bulk power markets.14

III. Notice of Inquiry

10. As part of Commission staff’s ongoing comprehensive review of the 

Commission’s financial data requirements, a series of public meetings were held in Fall 

2006 with both filers and users of FERC’s financial reports (Forms 1, 1-F, 2, 2-A and 3-

Q). On February 15, 2007, the Commission issued a Notice of Inquiry (NOI) in response 

 12 Quarterly Financial Reporting and Revisions to the Annual Reports, Order No. 

646, FERC Stats. & Regs. ¶ 31,158, order on reh’g, Order No. 646-A, FERC Stats. & 

Regs. ¶ 31,163 (2004). 

13 Accounting and Financial Reporting for Public Utilities Including RTOs, Order 

No. 668, FERC Stats. & Regs. ¶ 31,199 (2005), reh’g denied, Order No. 668-A, FERC 

Stats. & Regs. ¶ 31,215 (2006). 

14 Id.
Docket No. RM08-5-000 - 7 - 

to those discussions.15 The NOI sought comments on the need for changes or additions to 

the financial information reported on these forms. In response to the comments received, 

the Commission determined that each of the forms, representing different industries 

subject to the Commission’s jurisdiction, merited its own separate review. Accordingly, 

the Commission established a separate proceeding in Docket No. RM07-9-000, 

addressing only changes, additions, and amendments to the forms applicable to interstate 

natural gas companies.16

IV. Notice of Proposed Rulemaking

11. On January 18, 2008, the Commission issued a Notice of Proposed Rulemaking 

(NOPR) that proposed to revise the Form 1 (and Forms 1-F and 3-Q) and requested 

comments on several issues, including: (1) differences between Form 1 data and costs 

that are reflected in formula rate inputs, (2) the non-jurisdictional utility requirements and 

revising the Form 1-F reporting threshold for nonmajor utilities, (3) reporting for affiliate 

transactions, (4) filers whose reporting and accounting systems are based on a noncalendar fiscal year, (5) reporting for “Other Revenues,” and (6) the minimum threshold 

 15 Assessment of Information Requirements for FERC Financial Forms, Notice of 

Inquiry, FERC Stats. & Regs. ¶ 35,554 (2007). 

16 Revisions to Forms. Statements, and Reporting Requirements for Natural Gas 

Pipelines, Order No. 710, FERC Stats. & Regs. ¶ 31,267, order on reh’g, Order No. 

710-A, 123 FERC ¶ 61,278 (2008). 
Docket No. RM08-5-000 - 8 - 

reporting levels for certain line-item information.17 In addition, the NOPR proposed two 

non-form related rule changes, concerning notification of non-filing status and grants of 

extension of time for good cause. The NOPR also invited comments on software 

updates, revisions to the filing instructions, requests for additional information for 

particular accounts or schedules, and suggestions to improve the quality, completeness 

and consistency of data submissions.18

V. Discussion

A. Notice of Inquiry

12. In responding to the NOI, Form 1 public utility filers generally emphasized the 

difficulty and expense of Form 1 preparation, stated that the current scope of information 

sought is sufficient to evaluate jurisdictional rates, and objected to particular filing 

requirements as burdensome. In contrast, Form 1 users, including nonprofit publiclyowned utilities and state commissions, disagree — requesting that Form 1 provide 

additional information to permit more effective review to determine whether current and 

proposed rates are just and reasonable. 

 17 Revisions to Forms, Statements, and Reporting Requirements for Electric 

Utilities and Licensees, Notice of Proposed Rulemaking, 73 FR 5136 (Jan. 29, 2008), 

FERC Stats. & Regs. ¶ 32,627 (Jan. 18, 2008) (NOPR). 

18 These proposals were listed in an appendix to the NOPR, which is updated here 

with Commission responses and provided in Appendix B to this Final Rule. 
Docket No. RM08-5-000 - 9 - 

B. Notice of Proposed Rulemaking

13. In the NOPR, the Commission affirmed that the information reported in Forms 1, 

1-F and 3-Q is critical to the work of the Commission and stated its expectation that all 

filers would continue to follow the instructions and submit properly completed forms. 

The NOPR emphasized the importance of Form 1 data to the Commission, state 

commissions, utility customers and other interested persons as an important and primary 

source of information to assess whether rates charged remain just and reasonable or may 

be unjust and unreasonable. The NOPR stated that the purpose of Form 1, in particular, 

is to provide basic financial and operational information to allow the Commission, 

customers, and competitors to monitor a utility’s rates for jurisdictional services. Form 1 

is an essential tool in the Commission’s regulatory program. Form 1 makes publicly 

available the financial information upon which cost-based rates are developed and 

provides information on the financial operations of utilities. Form 1 and the underlying 

data are used in ratemaking and for customer rate and cost monitoring. In addition, 

because it reflects the Commission’s USofA, Form 1 ensures that such data is uniform 

and comparable between companies and reporting periods. Form 1 is not a substitute for 

a rate case filing or a projection of future financial performance, however. Instead the 

data enables the form’s users to monitor and assess a utility’s rates. 

14. Pursuant to the Commission’s comprehensive review of its financial reporting 

forms and based on the responses to the NOI, the Commission determined that wholesale 
Docket No. RM08-5-000 - 10 - 

changes were not justified, and instead proposed targeted adjustments to the existing 

reporting requirements. 

15. In response to the NOPR, the Commission received 13 timely comments, one 

motion to submit comments out-of-time, and one set of reply comments.19 These 

comments are summarized in the remainder of the discussion section. 

16. After careful consideration of the comments received, the Commission is adopting 

changes and revisions proposed in the NOPR with certain modifications and 

clarifications, as discussed below. 

17. No comments were filed objecting to the NOPR’s proposals concerning (i) 

accommodating filers whose books close on a non-calendar fiscal year, (ii) filing 

notifications of changes to non-filing status, (iii) adopting a good cause requirement for 

reviewing requests for extension of time, and (iv) providing for separate reporting of 

emissions allowances, such as nitrogen oxide (NOx) and sulfur dioxide (SO2). In fact, 

comments were received supporting several of these proposals, including the noncalendar year accommodation and emission allowances. Therefore, we adopt the 

proposals as set forth in the NOPR. 

18. In addition, several commenters proposed additional reporting requirements or 

modifications to the proposals made in the NOPR. To the extent such comments 

 19 A list of commenters is attached as Appendix C. 
Docket No. RM08-5-000 - 11 - 

proposed revisions that were feasible and in keeping with the goals expressed in the 

NOPR, the Commission has attempted to incorporate commenters’ suggestions as 

discussed below. The discussion in the “Commission Determination” sections addressing 

each NOPR proposal provides additional detail to clarify those proposals and respond to 

the comments. 

C. Effective Date 

19. The NOPR proposed calendar year 2009 as the effective date to implement these 

changes to the reporting requirements, stating: 

Accordingly, companies subject to the new requirements 

would file their new Form 3-Qs beginning with the Form 3-Q 

for the first calendar quarter of 2009 and their new Forms 1 

and 1-F in April 2010 for calendar year 2009. 

20. The Commission believes that this effective date provides sufficient time for filing 

companies to collect the information needed to fulfill the reporting obligations proposed 

in the NOPR and adopted in this Final Rule. Because the changes adopted here are 

limited in scope, filers have sufficient opportunity to make the necessary changes to their 

reporting systems to capture the necessary data in the detail needed to complete the new 

requirements contained in this Final Rule. This proposed effective date thus provides an 

adequate time for utilities to revise their information collection procedures, and filers will 

have several additional months before the first reporting deadline to implement the 

changes needed because the first report due is the Form 3-Q, a quarterly report, due in 
Docket No. RM08-5-000 - 12 - 

May 2009. Therefore, the Commission adopts the changes provided for in this Final Rule 

effective calendar year 2009, consistent with the date proposed in the NOPR. 

D. Proposed Revisions

1. Formula Rates

21. In response to comments requesting additional information to accommodate 

formula rate review, the NOPR proposed the addition of explanatory information when 

formula rate inputs deviate from data reported in Form 1. Specifically, the NOPR 

proposed to revise the Form 1 to require that, if the inputs to a formula rate deviate from 

what is currently shown in the Form 1, the filer must provide an explanation for the 

deviation in a footnote to the corresponding page, line and column where the specific 

data is reported. The Commission sought comment on this proposal.20 

Comments

22. Several commenters support the Commission’s proposal for filing utilities to 

explain departures from Form 1 data in formula rates. SDG&E, for example, notes that 

many utilities with formula rates already make periodic informational filings to explain 

the use of modified Form 1 data. SDG&E supports the NOPR proposal and characterizes 

the proposal as a pragmatic and narrowly-tailored effort to provide additional information 

that does not duplicate publicly available material, while avoiding a “one size fits all” 

 20 NOPR at P 46. 
Docket No. RM08-5-000 - 13 - 

modification to Form 1 that does not address the varieties of formula rates currently in 

effect or utilities’ uses of variations from Form 1 data. 

23. APPA also supports the Commission’s intent that utilities provide all information 

necessary for calculating formula rates, but questions whether the Commission’s proposal 

will achieve the desired effect. APPA states that the requirement that filers describe in 

footnotes details on how formula rates deviate from Form 1 information may be difficult 

to monitor because staff may lack the means to identify utilities subject to the formula 

rate information requirement. APPA suggests that the Commission require a new 

schedule for filers to identify their status in regard to formula rates, which would require 

a filer to indicate (1) whether it has formula rates; and (2) where to find all explanations 

for deviations between formula rates and Form 1 information (either informational filings 

or footnotes in connection with specific page, line and column numbers of Form 1). Such 

a schedule would ensure that a utility does not omit a necessary footnote and would also 

locate deviations from Form 1 data. APPA predicts that such a schedule would not 

change any Form 1 references currently contained in formula rates and should not add 

any substantial burden to respondents, because it would not repeat the information, but 

would simply reference the location of the information already compiled. 

24. BPA agrees that since formula rates routinely cite specific accounts and page 

numbers, the Commission should not revise Form 1 accounts or page numbers, so as to 

necessitate amendments to existing formula rates. BPA supports the use of explanatory 
Docket No. RM08-5-000 - 14 - 

footnotes, stating that the footnotes are an essential aspect of Form 1 and may provide the 

only means for a utility to explain, and Form 1 user to understand, the data. BPA 

suggests the need for additional enforcement of Form 1 requirements, including penalties 

for failure to meet footnote requirements. 

25. In addition, BPA requests clarification that a statement made in paragraph 41 of 

the NOPR, “[t]he annual rate adjustment may not initiate a rate proceeding and the 

customer’s recourse, if it believes the resulting rates are unjust and unreasonable, is to file 

a complaint under section 206 of the FPA,” is not intended to change the burden of proof 

in a section 206 proceeding involving a formula rate. Specifically, BPA requests the 

Commission clarify that the statement does not shift the burden of proof from the utility 

to establish that the formula is correctly applied or that the correct data is being used to 

populate the formula.21 

26. Nevada Companies suggests that a transmission provider should post the reasons 

for changes in formula rates on its web site within a prescribed period of time, which 

would provide immediate information to customers on changes in rates rather than having 

to wait for a quarterly or annual filing. 

27. TAPS strongly supports the NOPR’s effort to further the goal of timely 

transparency through inclusion of the relevant information in Form 1. TAPS questions 

 21 BPA states its understanding that the burden of proof otherwise remains on the 

party challenging a Commission-approved formula. 
Docket No. RM08-5-000 - 15 - 

the level of detail in an informational filing that would relieve a utility of the requirement 

to describe formula rate differences in Form 1. TAPS states that the rule should require 

that the transparency information be included in Form 1 submissions of each utility 

whose Form 1 data is input into a formula rate. TAPS proposes that waivers be 

considered where the utility can show that it is legally committed to make annual 

informational filings that will provide all of the data, of the same quality and reliability, 

that would otherwise have to be included in its Form 1, and will do so in time to facilitate 

rate monitoring by customers, regulators, and the public. TAPS also requests that the 

Final Rule require annual reporting of all historical cost, load, and revenue information 

that is an input into a Form 1 filing utility’s formula rate. 

28. The Michigan Commission requests that the Commission initiate a process to 

address problems associated with its review of utility transmission investment in 

conjunction with formula rates. The Michigan Commission states that a lack of 

necessary data reporting in combination with formula rates can shield utility investment 

decisions from review. The Michigan Commission suggests that the Commission initiate 

an inquiry, possibly a technical conference, to explore ways that formula rates can be 

reviewed. 

29. Several utility commenters object to the requirement to add footnotes to discuss 

differences between Form 1 financial information and formula rate inputs for wholesale 
Docket No. RM08-5-000 - 16 - 

rates.22 AEP believes that the Form 1 is a financial report and should continue to be a 

financial report and not a rate verification report. AEP claims that footnoting differences 

between Form 1 data and formula rate inputs would, for some filers like AEP, be 

extensive, voluminous and burdensome to comply with. AEP suggests that multiple rates 

will require reconciliation, including separate wholesale customer service rates and some 

regional transmission organization rates. AEP states that the Commission should obtain 

such information from the seller when needed on a case-by-case basis. AEP suggests that 

the additional detail need not be made public, and states that the information is better 

provided as a separate rate filing to be made whenever the formula rate is being changed 

or supported. 

30. EEI encourages the Commission not to add a requirement to Form 1 to explain 

departures from Form 1 information used as inputs to formula rates. EEI argues that 

companies should not be required to footnote Form 1 data to explain differences in 

formula rates, so long as they document changes to formula rate inputs, adhere to the 

approved formula rate tariffs, and provide information to the Commission and affected 

customers on request or via informational filings. 

31. EEI suggests that the Commission adopt an alternate policy, under which 

companies adopting formula rates would provide information to customers about rate 

 22 See AEP, EEI, FirstEnergy, and Duke comments. 
Docket No. RM08-5-000 - 17 - 

inputs, including underlying costs and cost increases, in sufficient detail to enable the 

customers to understand the basis for their rates. EEI states that if the Commission does 

impose a formula rate footnote requirement in Form 1, the Commission should: 

(1) clarify that the footnote is necessary only to explain departures from Form 1 data 

when a formula rate tariff calls for specific Form 1 data as inputs and different input data 

are used; (2) clarify that the footnote requirement applies only to cost-based rates, not to 

market-based rates (MBR); (3) specify that, if a seller files informational filings 

containing information about inputs to its formula rates, a footnote is not required; (4) 

specify that if customers have audit rights under a formula rate tariff, a footnote is not 

required; (5) specify that if a company has explained departures from Form 1 data as 

inputs to a formula rate elsewhere in information available to the Commission and 

customers on request, it is not required to do so again in Form 1; (6) specify that, if the 

footnote cannot be added before Form 1 is filed, it can be added at the next reporting 

cycle; and (7) address how the footnote should be prepared when multiple operating 

companies or gas and electric companies are involved and not all of those companies are 

reflected in a given Form 1. 

32. FirstEnergy requests that the Commission clarify that its proposal is not a blanket 

requirement on companies filing the Form 1 to include any changes on inputs to formula 

rates in a footnote to the relevant page in Form 1. Similarly, the Commission should also 
Docket No. RM08-5-000 - 18 - 

clarify that its proposed requirement would not preclude companies from submitting the 

formula input information in filings other than Form 1. 

33. FirstEnergy states that companies should not be required to submit informational 

filings or otherwise report situations in which formula rate inputs differ slightly from 

what is shown in Form 1, and requests the Commission to clarify whether such 

disclosures will now be required. To the extent that such information will be required, 

FirstEnergy does not believe that Form 1 is an appropriate vehicle for reporting 

information concerning a utility’s formula rates. FirstEnergy states that Forms 1 and 3-Q 

are financial statements providing information in accordance with the USofA and argues 

that the forms are not, and should not be, considered ratemaking documents to be used 

for ratemaking purposes. 

Commission Determination

34. In this Final Rule, as we explain below, we adopt the NOPR proposal that Form 1 

filers should provide explanatory information when formula rate inputs differ from Form 

1 reported amounts.23 That is, with regard to formula rates for which no informational 

filings are required to be regularly submitted to this Commission, we revise the Form 1 to 

require that, if the formula rate relies on Form 1 data and if the input amounts to that 

 23 Other than comprehensive formula rates, the Commission's regulations provide 

for automatic adjustment of only those costs specified in section 35.14 of our regulations 

(fuel adjustment clause). See Public Service Company of Oklahoma, 40 FERC ¶ 61,215, 

at 61,733 (1987). 
Docket No. RM08-5-000 - 19 - 

formula rate differ from what is shown in the Form 1, the filer must provide a narrative 

explaining the reason for the difference. The explanation must be provided in a footnote 

on the same page, line and column where the specific data is reported. 

35. As described above, EEI states that companies which provide service under 

formula rates should make additional information available if requested by customers, on 

an as-needed basis, if such information is not already being provided in the informational 

filings. EEI recommends that the Commission adopt an alternative policy, under which 

companies using formula rates would provide information to customers about rate inputs, 

including underlying costs and cost increases, in sufficient detail to enable the customers 

to understand any deviations to the inputs used in calculating the formula rates. 

36. With respect to EEI’s requests for various clarifications, we adopt portions of 

EEI’s recommendations as follows. Consistent with the NOPR proposal we limit the 

footnoting requirement so that it will only apply to utilities with formula rates that do not 

make regular (i.e., at least annual) informational filings of cost data with the Commission 

pursuant to the requirements of their formula rates (or for example, pursuant to the 

requirements of a Commission-approved settlement or a Commission directive). We 

believe it is unnecessary to require companies that are required to make regular 

informational filings to include a footnote in Form 1 because any difference from any 
Docket No. RM08-5-000 - 20 - 

Form 1 inputs used in formula rates should already be described in sufficient detail in 

their informational filings.24 

37. In addition, EEI requests clarification of the treatment of formula rates accepted 

under our MBR policies. We clarify that a rate is subject to the footnoting requirement if 

it relies on Form 1 data and is on file with the Commission. Such rates may be featured 

in tariffs of general applicability or individual rate schedules.25 We further adopt EEI’s 

suggestion that, if companies have formula rates but do not make such informational 

filings with the Commission, they must maintain sufficient records that explain the 

changes made to those inputs26 (and, of course, must adhere to the approved formula rate 

tariffs on file) and provide that information to the Commission, state commissions and 

affected customers on request. Furthermore, we clarify that if customers have audit 

rights under a formula rate, a footnote is still required, so that utilities can describe how 

the rate was derived (as described herein). 

 24 Thus, utilities that are required to make regular informational filings by their 

formula rates, a Commission-approved settlement, or other Commission order need not 

provide footnotes. These filers must nevertheless complete the new schedule provided in 

page 106. 

25 We clarify that we do not seek the explanatory information for fuel adjustment 

clauses, which are governed by separate polices established in the Commission’s 

regulations and which typically would not reference Form 1. See 18 CFR 35.14. 

26 This record-keeping requirement is in addition to any other Commission record 

keeping requirement, see, e.g., 18 CFR Parts 101, 125, including the footnoting 

requirement adopted in this Final Rule. 
Docket No. RM08-5-000 - 21 - 

38. With respect to EEI’s request that the Commission specify that footnote 

information that cannot be added before Form 1 is filed may be added at the next 

reporting cycle, we clarify that if the necessary information is not available at the time for 

filing (given that Form 1 is an annual report), the utility must provide the information in 

its next Form 1 filing. 

39. As stated in the NOPR, we do not propose to convert the Form 1 filing process 

into a rate proceeding. As noted by several commenters, Form 1 is an historical financial 

reporting document. However, Form 1 provides cost and revenue data that aids in 

evaluating the justness and reasonableness of rates in a ratemaking proceeding, and Form 

1 serves as a ready source of public information to assess on an ongoing basis the justness 

and reasonableness of utility rates. In particular, for a formula rate, Form 1 identifies 

costs that result in annual fluctuations in rates as costs rise and fall. Thus, Form 1 plays 

an important role in the Commission’s rate review process. 

40. A key component of this rate review process is the transparency provided by 

requiring utilities to make information on costs underlying rates publicly available. This 

cost information is, in turn, used by the Commission, state commissions, and customers 

to review and monitor a utility’s rates, which, as appropriate, may ultimately result in an 

investigation or a complaint proceeding. Thus, Form 1 is a valuable tool. Commenters’ 

attempts to establish a bright line between financial reporting and rate making are 

insufficient for the Commission to withdraw its proposals to seek information that will 
Docket No. RM08-5-000 - 22 - 

assist the Commission in carrying out its statutory obligations to ensure that rates are just 

and reasonable, and to assist others — including customers — with monitoring rates 

charged. 

41. The NOPR did not propose to revise the Commission’s USofA accounting 

requirements to track specific costs or cost estimates for future projects as suggested by 

TAPS and the Michigan Commission. Therefore, we will not adopt proposals to track 

additional costs that would require changes to the Commission’s accounting 

requirements. 

42. In response to APPA’s comments concerning how Commission staff will 

determine whether a utility is subject to a regular informational filing requirement for its 

formula rate, we note that the existence of such a filing requirement is a matter of public 

record for each formula rate. That is, the requirement that a utility make a regular 

informational filing describing the information that will be used to populate the formula 

rate is typically established in the rate proceeding accepting the formula rate. If an 

interested entity believes that a utility has failed to include the required footnotes, or that 

a utility has not responded in a timely manner to a request for an explanation of the 

applicable formula rate and the inputs to that rate, it should discuss the matter with the 

utility and, if not satisfied, may, among other things, notify the Commission through our 

enforcement Hotline and the Commission’s Office of Enforcement will take appropriate 

action. 
Docket No. RM08-5-000 - 23 - 

43. Based on the record in this proceeding, the Commission does not anticipate that 

this reporting requirement will be unduly burdensome because the information is already 

available and can be transposed to a footnote. 

44. Several filing utilities request the Commission to clarify the scope of the formula 

rate footnoting requirement. Initially, as noted above, the Commission clarifies that a 

filing company should footnote differences from Form 1 data in formula rates that are on 

file with this Commission and that rely on Form 1 data, and that such rates may be 

featured in tariffs of general applicability or individual rate schedules.27 The 

Commission also clarifies that it is not necessary to provide a detailed reconciliation. 

The Commission anticipates that the footnotes would contain a simple narrative 

explaining how the “rate” (or billing) was derived if different from the reported amount 

in the Form 1. For instance, differences could be due to: (i) application of a percent 

allocation factor for gross transmission plant that is OATT related; (ii) excluding 

particular items such as step-up transformer investment; (iii) deducting amounts for 

transmission for others from total transmission expenses or applying an OATT 

transmission factor; or (iv) excluding particular cost items from administrative and 

general expenses or application of an OATT labor factor. This list is not exhaustive, we 

 27 As noted above, we do not seek the explanatory information for fuel adjustment 

clauses, which are governed by separate polices under the Commission’s regulations and 

typically do not reference Form 1. See 18 CFR 35.14. 
Docket No. RM08-5-000 - 24 - 

caution, but is strictly for illustration purposes; the Commission anticipates that similar 

issues would be footnoted in Form 1. The description should describe the difference, 

including any reference to a Commission proceeding approving the difference. Such an 

explanation should be sufficient to alert interested parties of the deviation and to permit 

them to estimate and evaluate the impact of the departure on rates.28 In this fashion, 

interested entities should be able to, with reasonable accuracy, monitor rates in light of 

current costs and available financial data. 

45. In response to suggestions that formula rate information be centralized, a new 

schedule (page 106) will be incorporated in Form 1 on which filers will (1) indicate 

whether they have formula rates; (2) provide details about the formula rates; (3) indicate 

whether the filer makes regular informational filings and the location of the filings (e.g., 

accession numbers) on the Commission’s eLibrary website; and (4) summarize, if 

required,29 the differences between the Form 1 amounts and any amounts included in a 

formula rate as described above.30 

 28 The information contained in a formula rate footnote (as for any Form 1 

footnote) should be specific to the data provided in the form, and not simply transferred 

from consolidated financial statements that may reflect different assumptions and 

reporting requirements. 

29 Whether or not a public utility or licensee must provide this information is 

addressed above. 

30 Revised Form 1 pages affected by this Final Rule are provided in Appendix A. 
Docket No. RM08-5-000 - 25 - 

46. AEP is concerned that reporting may be difficult because of the number and 

variety of rate schedules and tariffs that may be covered by this requirement. As stated 

above, we do not anticipate that this requirement need rise to the level of an accounting 

reconciliation; a narrative description (with reference to a rate proceeding adopting the 

difference) may suffice. 

47. In addition, a utility is not precluded from filing modifications to its formula rates 

to make cost references consistent with Form 1 reporting requirements as they are 

updated.31 

48. In response to BPA and the Michigan Commission, we clarify that this Final Rule 

does not change our policies with respect to the burden of proof associated with 

challenges to previously approved formula rates under section 206.32 Form 1 is not filed 

pursuant to sections 205 or 206 of the FPA and, therefore, its submittal will not initiate a 

 31 The Commission reiterates that utilities that are required to make regular 

informational filings by their formula rates, a Commission-approved settlement, or other 

Commission requirement (e.g., a Commission requirement imposed as a condition of 

acceptance of the formula rates) need not provide footnotes. These filers must 

nevertheless complete the new schedule provided in page 106. 

32 See Order No. 710 at P 12 (noting that despite changes made to gas reporting 

forms, a party filing a complaint has the burden to show why the information in the 

Commission’s financial forms supports an allegation that the existing rates are not just 

and reasonable, and that the changes adopted in Order No. 710 do not limit an entity’s 

rights under governing law and the Commission’s regulations, nor change the 

Commission’s obligation to rule on complaints, petitions, or other requests for relief 

based on a full record and substantial evidence). 
Docket No. RM08-5-000 - 26 - 

rate proceeding or investigation. A rate proceeding is initiated by a rate filing under 

section 205, or an investigation initiated either in response to a complaint or pursuant to a 

notice of Commission investigation under section 206. Additional information to assess 

jurisdictional rates may be requested from the utility or sought through discovery in an 

appropriate proceeding; the Commission’s actions here do not, for example, affect the 

scope of discovery in litigated proceedings. 

49. In addition, we reject TAPS’ proposals to change the Commission’s accounting as 

beyond the scope of this proceeding, which relates to reporting requirements for the 

various accounts defined by the USofA, and we reject the Nevada Companies’ proposal 

to revise our OASIS website posting requirements; both should be addressed in more 

appropriate proceedings reviewing the Commission’s accounting and OASIS regulations. 

50. With respect to the Michigan Commission’s suggestion that the Commission 

initiate an inquiry into the Commission’s formula rate policies and whether formula rates 

can shield future utility investment decisions from review, the Commission declines to 

initiate such an investigation. The NOPR rejected calls for reporting information on 

future transmission investments, stating that Form 1 is intended to provide information on 

a utility’s financial activities for the reporting year, but does not include projections of 

future costs.33 Comments filed in response to the NOPR have not persuaded us to change 

 33 NOPR at P 54. 
Docket No. RM08-5-000 - 27 - 

our views. Should an entity desire to question the prudence of a utility’s transmission 

investment decisions, it may file a complaint with the Commission.34 

2. Filing Thresholds for Form 1 

51. The NOPR proposed to eliminate the filing requirement for utilities that are not 

subject to the Commission’s jurisdiction because they are not public utilities under Part II 

of the FPA, but make sales that meet or exceed the threshold for meeting the 

Commission’s Forms 1 and 3-Q reporting requirements.35 The NOPR also sought 

comment on whether to revise the definitions for major and nonmajor utilities, inviting 

specific suggestions for how this might be done with justifications for proposed 

thresholds.36 The NOPR mentioned that the Commission was aware of five nonjurisdictional utilities that otherwise met or exceeded the threshold for reporting: Alaska 

Electric and Power Co.; CenterPoint Energy Houston Electric, LLC; Hawaii Electric 

Light Co., Inc.; Hawaiian Electric Co., Inc.; and Maui Electric Co., Ltd. 

52. The NOPR cited an order where the Commission recently granted waiver of the 

financial form filing requirements under such circumstances. In Morenci Water and

 34 Preventing Undue Discrimination and Preference in Transmission Service, 

Order No. 890, 72 FR 12,266 (March 15, 2007), FERC Stats. & Regs. ¶ 31,241 at P 435 

(2007), order on reh’g, Order No. 890-A, 73 FR 2984 (Jan. 16, 2008), FERC Stats. & 

Regs. ¶ 31,261 (2007), order on reh’g, Order No. 890-B, 123 FERC ¶ 61,299 (2008). 

35 NOPR at P 50. 

36 Id. P 48. 
Docket No. RM08-5-000 - 28 - 

Electric Co., the Commission granted a waiver from the requirement of §§ 141.1 and 

141.400 of the Commission’s regulations that utilities who are not public utilities under 

Part II of the FPA but who otherwise meet the threshold filing requirements for Forms 1, 

1-F and 3-Q must comply with the reporting requirements established in the 

regulations.37 

Comments

53. No commenter objected to these proposals. International Transmission proposes, 

however, that non-major electric utilities and non-jurisdictional utilities that belong to a 

joint rate zone be required to file Form 1 and that, for purposes of the filing thresholds, 

all of the electric utilities in a joint rate zone should be deemed major electric utilities. 

International Transmission thus proposes that, in addition to the numerical filing 

thresholds, the General Instructions to Part 101 be revised to require that: (1) nonmajor 

electric utilities in joint rate zones with major electric utilities be required to file Form 1; 

and (2) non-jurisdictional utilities in joint rate zones with jurisdictional public utilities 

also be required to file Form 1. 

Commission Determination 

54. In this Final Rule we are removing the words “whether or not the jurisdiction of 

the Commission is otherwise involved” from §§ 141.1(b) and 141.400(b), which establish 

the filing requirements for Form 1 and Form 3-Q, respectively. With this change, 

 37 Morenci Water and Electric Co., 121 FERC ¶ 61,024 (2007). 
Docket No. RM08-5-000 - 29 - 

companies that are not subject to the Commission’s jurisdiction because they are not 

public utilities (or licensees) need no longer file Form 1 or 3-Q. If a company is 

concerned that it may still fall within the revised requirements of §§ 141.1(b) or 

141.400(b), but nevertheless should be exempted from filing Forms 1 and 3-Q, it may 

continue to seek an individual waiver from the Commission. No commenter, we add, 

objected to the proposal to cease requiring filing by companies that do not otherwise fall 

under the Commission’s jurisdiction, but meet the minimum filing requirements found in 

§§ 141.1 and 141.400 of the Commission’s regulations. 

55. The Commission rejects International Transmission’s proposal to revise the 

definitions that distinguish major and nonmajor utilities, to require utilities that 

participate in joint rate zones with major utilities to also file Form 1. International 

Transmission’s proposal expands the reporting requirement so that it would apply to nonjurisdictional entities and also would require small utilities to file Form 1, regardless of 

the reporting threshold. International Transmission’s proposal would unreasonably 

increase the reporting burdens on small utilities. Therefore, we reject the proposal. 

3. Affiliate Transactions

56. To provide further transparency and improve the detection of cross-subsidization, 

the NOPR proposed to add a new schedule and page 429, “Transactions with Associated 

(Affiliated) Companies,” providing information concerning affiliate transactions. The 

NOPR proposed that filers would report the following: (1) a description of the good or 
Docket No. RM08-5-000 - 30 - 

service charged or credited; (2) the name of the associated (affiliated) company; (3) the 

USofA account charged or credited; and (4) the amount charged or credited.38 

Comments

57. Several commenters support the proposal,39 and some include proposals to expand 

the reporting requirement.40 Others object to the affiliate transaction reporting 

requirement41 or argue that such a requirement would be duplicative of other reporting 

obligations, unnecessary and burdensome.42 

58. APPA supports the Commission’s proposal to add the new schedule to collect 

information on affiliate transactions. The Michigan Commission states that detailed 

descriptions of costs allocated to jurisdictional operations from affiliates are essential to 

detect cross-subsidization. It also requests clarification whether the Commission intends 

that an allocation for common facilities that are billed to one or more affiliates be 

reported as an affiliate transaction. The Michigan Commission requests that the 

Commission require additional detail, consisting of a description of all allocation factors 

 38 NOPR at P 51-52. 

39 APPA and Michigan Commission comments. 

40 International Transmission, and SDG&E comments. 

41 See AEP, EEI, MidAmerican, and Nevada Companies comments. 

42 FirstEnergy and Duke comments. 
Docket No. RM08-5-000 - 31 - 

used by the utility and its affiliates and an explanation of how “direct” and “common” 

costs are defined and implemented. 

59. Nevada Companies states that affiliate transactions should be reported by type of 

service provided and goods transferred. The Nevada Companies note that reporting 

amounts by types of services provided would link this report to master service 

agreements entered into by many affiliated companies. They also request a definition of 

good or service. 

60. SDG&E recommends that the Commission clarify that the affiliate transaction 

information required to be provided is limited to transactions between a jurisdictional 

utility and its affiliates and does not include transactions solely between or among the 

affiliates. 

61. Nevada Companies requests that affiliate transaction information only be reported 

annually for companies that prepare similar information to fulfill state requirements, 

suggesting the proposed reporting requirement could be met by state oversight. AEP 

objects to an affiliate transaction reporting requirement and suggests that the issue is a 

state regulatory matter.43 

62. Duke requests that the Commission clarify that the new page 429 is not intended 

to require the reporting of affiliate transactions between the electric utility and centralized 

 43 See also Nevada Companies comments. 
Docket No. RM08-5-000 - 32 - 

service companies, as this information is already reported in FERC Form No. 60 (Form 

60). FirstEnergy states that the new page would result in a duplication of effort since the 

same information is already reported to the Commission in other FERC forms, including 

the Form 60, and other places in Form 1, such as page 332, Transmission of Electricity 

by Others and pages 326-327, Purchased Power. At a minimum, FirstEnergy requests 

that a set of parameters be established for reporting the information requested, and 

suggests filers be permitted to report the information by general category rather than by 

individual transactions. 

63. MidAmerican objects to detailed reporting of each affiliate transaction as 

unnecessarily burdensome and states that the information is already being provided in 

other publicly available documents. MidAmerican requests that the Commission limit 

any affiliate transaction reporting requirement and (1) establish an aggregate annual 

transaction reporting threshold of the greater of (a) $250,000 per affiliate or (b) one onehundredth of one percent (.01%) of the electric utility’s operating revenues44 and (2) 

exempt transactions based on regulator-approved tariffs.45 The Nevada Companies 

 44 SDG&E also supports a $250,000 reporting threshold for affiliate transactions. 

45 In particular, MidAmerican notes that it is bound to serve affiliates due to its 

provision of service to 2.5 million retail customers. MidAmerican argues that provision 

of service in accordance with a state-regulator-approved tariff precludes the opportunity 

for cross-subsidization or preferential service. MidAmerican states that the same holds 

true where MidAmerican purchases tariff services from an affiliate of its parent 

(Berkshire Hathaway). 
Docket No. RM08-5-000 - 33 - 

request that $100,000 be set as a reasonable minimum amount to report the transfer of a 

good, or an aggregate amount of service. 

64. EEI states that the affiliate transaction reporting proposal is inconsistent with the 

Commission’s decisions in Orders No. 707 and 708 not to require additional reporting.46 

International Transmission and Nevada Companies object to an affiliate reporting 

requirement that would apply to transactions between regulated public utilities. 

International Transmission cites the Commission’s proposal that page 429 is to “provide 

further transparency and improve the detection of cross-subsidization.”47 International 

Transmission states that a broad, one-size-fits-all requirement that includes reporting of 

transactions between affiliated regulated public utilities would not produce useful 

information for detecting improper cross-subsidization for the benefit of non-utility 

affiliates. International Transmission argues that the regulated affiliates’ Form 1 filings 

already provide ample transparency and that the affiliate transaction reporting 

requirement is therefore not necessary for affiliate transactions between regulated public 

utilities. 

 46 Cross-Subsidization Restrictions on Affiliate Transactions, Order No. 707, 

73 FR 11013 (Feb. 29, 2008), FERC Stats. & Regs. ¶ 31,264, order on reh’g, Order No. 

707-A, 73 FR 43072 (Jul. 24, 2008), FERC Stats. & Regs. ¶ 31,272 (2008); Blanket 

Authorization Under FPA Section 203, Order No. 708, 73 FR 11003 (Feb. 29, 2008), 

FERC Stats. & Regs. ¶ 31,265, order on reh’g, Order No. 708-A, 73 FR 43066 (Jul. 24, 

2008), FERC Stats. & Regs. ¶ 31,273 (2008). 

47 Citing NOPR at P 52. 
Docket No. RM08-5-000 - 34 - 

Commission Determination

65. Consistent with our natural gas reporting requirements established in Order No. 

710, we will adopt the NOPR proposal and incorporate new page 429, Transactions with 

Associated (Affiliated) Companies. Consistent with the reporting threshold established 

in Order No. 710, the schedule instructions incorporate a $250,000 threshold for 

reporting individual transactions. While some commenters suggested alternative 

thresholds, we find that the threshold we adopt here reasonably balances the burden while 

still reporting needed information. Therefore, we will not adopt the suggested alternative 

proposals. 

66. In response to requests that the Commission specify the affiliated or associated 

company transactions to which new page 429 applies, we clarify that the schedule applies 

to all affiliated/associated company non-power goods and services transactions including 

those with other regulated public utilities, centralized and other service companies, and 

other affiliated or associated companies providing non-power goods and services to the 

respondent or receiving non-power goods or services from the respondent. However, we 

also clarify that page 429 does not apply to transactions between affiliate or associate 

companies that do not include the respondent utility. 

67. We disagree with EEI that the “affiliate transaction reporting proposal is 

inconsistent with the Commission’s decisions in Orders No. 707 and 708 not to require 

additional reporting.” We note that, although Order No. 707 did not adopt a reporting 
Docket No. RM08-5-000 - 35 - 

requirement, at the same time the NOPR in this proceeding alerted interested persons that 

the Commission was separately proposing the additional affiliate transaction reporting 

requirements that are adopted in this Final Rule. Order No. 707 was intended to update 

our rate filing regulations to reflect our expanded authority following the repeal of the 

Public Utility Holding Company Act of 1935 (PUHCA 1935).48 In Order No. 707, the 

Commission codified in its rate regulations49 restrictions on affiliate transactions between 

franchised public utilities that have captive customers or that own or provide transmission 

service over jurisdictional transmission facilities, on the one hand, and their marketregulated power sales affiliates or non-utility affiliates, on the other. Order No. 707 

addressed both power and non-power goods and services transactions between the utility 

and its affiliates and specifically power sales affiliates. This proceeding provides 

expanded affiliate/associate transaction reporting to facilitate monitoring 

affiliate/associate non-power goods and services transactions as part of a comprehensive 

proceeding to update our reporting requirements. Thus, while Order No. 707 did not 

expand reporting to implement the revised rate filing regulations adopted in the wake of 

the repeal of PUHCA 1935, this proceeding is based on the need for data to monitor on 

an ongoing basis utility rates to ensure that they remain just and reasonable. On the basis 

 48 15 U.S.C. 79a, et seq. 

49 18 CFR Part 35. 
Docket No. RM08-5-000 - 36 - 

of the record in this proceeding, we find that the additional reporting requirement adopted 

here is appropriate because it will assist the Commission and the public in monitoring a 

utility’s rates. 

68. Order No. 708 adopted a blanket authorization permitting certain dispositions 

under section 203, such as the disposition of less than 10 percent of public utility voting 

securities to a holding company that does not thereby exceed certain voting interest 

thresholds. The requirements in Order No. 708 to report security dispositions made 

pursuant to blanket authorizations were designed to implement the new authorizations. 

Order No. 708 does not establish general reporting requirements or polices and the 

requirements established there are not relevant to the proposal adopted in this Final Rule. 

69. The Form 60 requirements are limited to total direct costs, total indirect costs and 

total costs of goods and services provided to each associate company by centralized 

service companies. The new reporting requirement provides more detailed information 

(in the form of individual transactions) about non-power goods and services provided by 

utilities to other affiliated/associated companies and non-power goods and services 

provided by affiliated/associated companies to utilities which is lacking in the Form 60 

requirements. While the proposed Form 1 information requirement might be part of the 

total reported in Form 60, at least for transactions where centralized service companies 

provide non-power goods and services to the respondent utility, it is not duplicative. As 

compared to the other information in Form 1, we clarify that the new requirements apply 
Docket No. RM08-5-000 - 37 - 

only to non-power goods and services and thus do not apply to power sales. Therefore, 

we find that the new reporting requirements have not been shown to be duplicative of 

other requirements. 

70. The Michigan Commission requests clarification whether the Commission intends 

that an allocation of common facilities that are billed to one or more affiliates be reported 

as an associate/affiliate transaction. We clarify that apportionment of costs of a common 

facility should be reflected on page 429. Some examples of items that could be reported 

as an associate/affiliate transaction include the amount of rent or property apportioned to 

a utility for a common building; the apportioned cost of a computer network along with 

costs to maintain such network, the apportioned cost of a garage used to house common 

trucks; the apportioned cost of phone networks and other phone costs. The allocation 

should also be disclosed as required in Instruction 3 of page 429 which requires the basis 

of the allocation. 

71. Nevada Companies requests that affiliate transaction information need only be 

reported annually for companies that prepare similar information to fulfill state 

requirements, suggesting the proposed reporting requirement could be met by state 

oversight. AEP objects to an affiliate transaction reporting requirement and suggests that 

the issue is a state regulatory matter. We disagree that this information is a state 

regulatory matter; the information is needed for monitoring Commission-jurisdictional 

rates. Also, more generally, not all states provide oversight. Furthermore, as noted 
Docket No. RM08-5-000 - 38 - 

above, this action is consistent with the Commission’s adoption of a similar requirement 

for natural gas companies in Order No. 710. 

72. International Transmission asserts that a broad, one-size-fits-all requirement that 

includes reporting of transactions between affiliated, regulated public utilities would not 

produce useful information for detecting improper cross-subsidization for the benefit of 

non-utility affiliates. While the Commission appreciates that additional requirements 

may be useful to address concerns in particular cases, the Commission believes that the 

reporting requirement adopted here will provide useful information and will aid in 

detecting improper cross-subsidization. 

73. We clarify, for purposes of page 429, that by “goods” we mean any goods, 

equipment (including machinery), materials, supplies, appliances, or similar property 

(including coal, oil, or steam, but not including electric energy, natural or manufactured 

gas, or utility assets) which is sold, leased, or furnished, for a charge. Similarly, for 

purposes of page 429, by “service,” we mean any managerial, financial, legal, 

engineering, purchasing, marketing, auditing, statistical, advertising, publicity, tax, 

research, or any other service (including supervision or negotiation of construction or of 

sales), information or data, which is sold or furnished for a charge.50 These definitions 

 50 See 18 CFR 366.1; 18 CFR 367.1(a)(20) and (44); Repeal of the Public Utility 

Holding Company Act of 1935 and Enactment of the Public Utility Holding Company 

Act of 2005, Order No. 667, FERC Stats. & Regs. ¶ 31,197 (2005), order on reh’g, Order 

No. 667-A, FERC Stats. & Regs. ¶ 31,213, order on reh’g, Order No. 667-B, FERC Stats. 

(continued) 
Docket No. RM08-5-000 - 39 - 

should address the concerns of commenters who are uncertain whether a particular charge 

or arrangement need be reported as an affiliate transaction. 

4. CPA Certification for a Non-Calendar Fiscal Year 

74. The NOPR noted that, although Form 1 is filed on a calendar year basis, some 

reporting companies operate on a non-calendar fiscal year. In response to comments 

describing the burden to prepare two sets of audited statements faced by companies that 

do not use a calendar fiscal year, the NOPR proposed to eliminate the burden by 

requiring public utilities using non-calendar fiscal years to continue to file annual reports 

each April, and file a certified set of financial statements following the end of the fiscal 

year.51 The second, certified set of financial statements is to be independently audited 

and accompanied by a certified public accountant (CPA) certification as required by the 

Commission’s regulations.52 This revision will permit non-calendar year public utilities 

to avoid duplicative audits. 

75. This approach is consistent with the Commission’s existing practice; i.e., the 

Commission’s historical practice of granting individual requests for waiver of the CPA 

certification requirement for Forms 1 and 1-F filers so long as the certification 

 

& Regs. ¶ 31,224 (2006), order on reh’g, Order No. 667-C, 118 FERC ¶ 61,133 (2007) 

(incorporating definitions from Securities and Exchange Commission, Public Utility 

Holding Company Act of 1935 Release No. 125 (1936)(codified at 17 CFR 250.80)). 

51 NOPR at P 56. 

52 18 CFR 41.11. 
Docket No. RM08-5-000 - 40 - 

accompanies the fiscal year-end financial information filed after the annual Form 1 or 1-F 

is submitted.53 

Comments

76. No commenter objects to the proposal. EEI encourages the Commission to clarify 

that, with adoption of the NOPR’s proposed amendment to 18 CFR § 41.11, companies 

will no longer need to seek a waiver, or if a company must continue to seek a waiver they 

need do so only once and the waiver would then apply in perpetuity barring a subsequent 

filing by the company or notice by the Commission. 

Commission Determination

77. We adopt the NOPR proposal to revise § 41.11 to accommodate filing parties who 

follow accounting and reporting practices under which their fiscal year does not match 

the calendar year. Companies seeking waiver of the calendar-year independent 

accountant certification requirement must request authority to file the independent 

accountant certification based on their fiscal year information. Once the request is 

granted, however, we will not require the company to annually renew the request. 

Instead, the company must annually notify the Commission in writing at the time that it 

files its initial annual report that it will continue to file the certification based on fiscal 

year information (or is returning to a calendar year reporting). The certification for fiscal 

 53 See, e.g., PacifiCorp, Docket Nos. AC00-20-000 and AC00-20-001 (Apr. 14, 

2000) (unpublished letter order). 
Docket No. RM08-5-000 - 41 - 

year companies must be filed no later than 150 days after the end of their fiscal year 

which is a period comparable to calendar year filers. 

5. “Other Revenues” (Pages 300-301)

78. The NOPR proposed to expand the reporting of “Other Revenue” data referenced 

in pages 300 and 301 to enable the Commission and the forms’ users to achieve a 

meaningful understanding of the nature of the business activities from which the revenues 

are derived.54 Greater detail concerning these revenue accounts could provide data that 

would enable the Commission and utility customers to identify revenues received by the 

filing companies and to understand how these transactions may affect the companies’ 

cost of service. To that end, the NOPR proposed to revise the instructions on page 300 to 

require that details of items included in Other Revenues be reported in a footnote to 

pages 300-301. 

79. Page 300 itemizes total electric operating revenues, composed of various types of 

sales of electricity (consisting of accounts 440-449), less provision for rate refunds, in 

addition to Other Operating Revenue. The data provided on page 300 on Other 

Operating Revenue includes accounts 450 (forfeited discounts), 451 (miscellaneous 

service revenues) and 453-457.2 (including water and water power sales, rents, other 

 54 NOPR at P 57. NOI commenters coined the phrase “Other Revenue” to refer to 

the unspecified revenues referenced on pages 300 and 301. In response to comments on 

the NOPR proposal, the scope of the Other Revenue reporting requirement is more 

precisely defined in the discussion below. 
Docket No. RM08-5-000 - 42 - 

electric revenues, regional control service revenues and miscellaneous revenues). 

Because Form 1 contains only a cumulative total for the reporting year of the various 

Other Revenues, the NOPR proposed that filers include a detailed breakdown of the 

various sources of other revenues in a footnote to page 300 for any revenues not 

otherwise specified on pages 328-330, Transmission of Electricity for Others (including 

transactions referred to as “wheeling”). 

80. Form 1 reports Total Other Operating Revenues (page 300, line 26), which include 

Revenues from Transmission of Electricity for Others (page 300, line 22, account 456.1). 

The details of account 456.1 are reported on pages 328-330, (Transmission of Electricity 

for Others (including transactions referred to as “wheeling”)). The NOPR proposed two 

changes and requested comment. First, the NOPR proposed to revise the instructions on 

page 300 to require that for any revenues reported on line 26, excluding amounts reported 

on line 22, the filer must in a footnote report details on the other line items to page 300.55 

Second, the NOPR asked for specific comment on a New York Commission proposal to 

clarify the instructions on pages 300-301 to indicate that delivery-only revenues shall be 

recorded as Other Electric Revenues (Account 456), while sales of electricity shall be 

 55 Id. 
Docket No. RM08-5-000 - 43 - 

recorded on a full-service basis (Accounts 440 through 448), to reflect that the USofA 

does not unbundle electric operating revenues.56

Comments

81. The New York Commission supports the proposal, stating that the Commission 

should require electric utilities to report other income and other income deductions in 

order to assess whether rates are just and reasonable. The Michigan Commission also 

supports the proposal, describing Form 1 as currently reporting a cumulative total for 

only two broad categories of revenue: “Revenue from Transmission of Electricity for 

Others” and “Other Electric Revenues.” The Michigan Commission requests that the 

Commission require filers to provide additional details, i.e., revenue for wholesale 

distribution, retail distribution, opportunity sales, and retail sales (with a breakout of 

bundled and customer choice sales); breakouts by state jurisdiction and rate schedule; and 

reporting of the value of “unbilled sales.” The Michigan Commission also requests that 

the Commission require a breakout of “Revenue from Transmission for Others” by rate 

schedule. 

82. Nevada Companies suggest $500,000 as a reasonable minimum threshold for 

reporting Other Revenues and also suggests, as with affiliate transactions, that the items 

be reported by category and not by transaction. 

 56 The New York Commission proposal is provided as line item 36 of Appendix B 

(corresponding to Appendix C of the NOPR). 
Docket No. RM08-5-000 - 44 - 

83. EEI requests that the Commission clarify that the requirement for additional 

details on page 300 applies only to FERC account 456, Other Electric Operating 

Revenues, and specify whether the requirement applies to account 457.2, Miscellaneous 

Revenues used by RTOs and ISOs. EEI requests that the Commission establish a 

threshold of $500,000 or 10 percent of the balance in the FERC account, whichever is 

greater. 

84. Duke is opposed to the Commission’s proposal to add a footnote to page 300 in 

order to provide users with additional detail related to all Other Revenues not otherwise 

specified on pages 328-330, arguing that the benefit from the proposed requirement is 

outweighed by the additional burden placed on filers. Duke proposes that any breakout 

requirement should only apply to the two accounts that are truly “miscellaneous” in 

nature, account 451, Miscellaneous Service Revenues, and account 456, Other Electric 

Operating Revenues, and should only require categorization of the types of charges 

included in these two accounts. 

85. FirstEnergy objects to the New York Commission’s proposed revision. 

FirstEnergy generally notes that reporting practices should follow accounting practices. 

If, however, the Commission is proposing a change in accounting practice, FirstEnergy 

submits that this proceeding is not the appropriate forum to propose such a change, which 

should be addressed in a separate rulemaking preceding that does not relate solely to 

proposals on reporting requirements. 
Docket No. RM08-5-000 - 45 - 

86. APPA supports the proposal to clarify the pages 300-301 instructions to 

distinguish unbundled, delivery-only transactions from the remainder of the transactions 

and provide consistency in filer data. Cogentrix supports the New York Commission 

proposal that delivery-only revenues be recorded in Other Electric Revenues (account 

456), while sales of electricity (including bundled sales) be recorded in accounts 440 

through 448. 

Commission Determination

87. In this Final Rule, we adopt the NOPR proposals to revise the instructions on 

pages 300 and 301. Several commenters requested clarifications to the scope of the 

additional reporting requirement for Other Revenues. In response, we clarify that a filing 

company shall provide in a footnote information on “any revenues” not otherwise 

specified in the breakdowns of Other Revenues provided on page 300 or on pages 

328-330.57 The Commission clarifies that the information provided on these pages 

should be comprehensive, meaning that any and all revenues should be described for each 

source of income in the same degree of detail as for the specific items for which a 

 57 Page 300 already tracks various specific sources of other revenue, including 

Forfeited Discounts (account 450), Sales of Water and Water Power (account 453), Rent 

from Electric Property (account 454), Interdepartmental Rents (account 455), Revenues 

from Transmission of Electricity of Others (account 456.1) and Regional Control Service 

Revenues (account 457.1). These accounts are not subject to the additional reporting 

requirement (or the $250,000 reporting threshold). Page 300 also incorporates three 

general accounts, Miscellaneous Service Revenues (account 451), Other Electric 

Revenues (account 456), and Miscellaneous Revenues (account 457.2). 
Docket No. RM08-5-000 - 46 - 

breakout is already required. For example account 456, Other Electric Revenues would 

include, among other items, commission on sale or distribution of electricity of others 

when sold under rates filed by such others; compensation for minor or incidental services 

provided for others such as customer billing, engineering, etc.; profit or loss on sale of 

material; and supplies not ordinarily purchased for resale and not handled through 

merchandising and jobbing accounts. The Commission anticipates that the additional 

information should provide details on the amounts included in the general accounts 

(account 451, Miscellaneous Service Revenues, line 17 of page 300; account 456, Other 

Electric Revenues, line 21; and account 457.2, Miscellaneous Revenues, line 24) and that 

such reporting, along with the detail on page 300, should account for all sources of the 

filing company’s other revenue. 

88. In the NOPR, the Commission did not propose a threshold for disclosing “Other 

Revenues.” Nevada Companies suggest $500,000 as a reasonable minimum threshold 

guideline for reporting Other Revenues. EEI requests that the Commission establish a 

threshold of $500,000 or 10% of the balance in the USofA account, whichever is greater. 

Consistent with the statements the Commission made in Order No. 710-A when adopting 

the threshold amounts for grouping natural gas items, we find that the absence of a 

minimum threshold could add a substantial burden to the forms’ filers.58 We find that an 

 58 See Order No. 710-A at P 7. 
Docket No. RM08-5-000 - 47 - 

alternative threshold of $250,000 is reasonable and not unduly burdensome, and will, 

nevertheless, provide meaningful data to this Commission, state commissions, and 

customers. We also note that the threshold here is consistent with that used in FERC 

Form No. 2 (Form 2). In keeping with this analysis, the Commission adopts a minimum 

threshold of $250,000 per source of income, consistent with the amounts reported on 

page 308 of Form 2, which reports other operating revenues. 

89. The Michigan Commission requests that the Commission require filers to provide 

additional breakouts of revenue for wholesale distribution, retail distribution, opportunity 

sales, and retail sales (with a breakout of bundled and customer choice sales); breakouts 

by state jurisdiction and rate schedule; and reporting of the value of “unbilled sales.” 

Michigan Commission also requests that the Commission require a breakout of “Revenue 

from Transmission for Others” by rate schedule. The requests by Michigan Commission 

would require changes to the Commission’s accounting requirements. We are not 

prepared to, and did not propose in the NOPR to, revise our accounting requirements at 

this time; the Michigan Commission proposals are beyond the scope of our original 

proposal and so we decline to adopt them at this time. 

90. With regard to commenters’ suggestions that a delivery-only transaction be 

separately disclosed, rather than included in electric sales (accounts 440-447), such an 

accounting requirement would require revision to the USofA, which is beyond the scope 
Docket No. RM08-5-000 - 48 - 

of this proceeding and which we decline to do at this time. Therefore, we will not require 

companies to separate out delivery-only transactions in their Form 1. 

6. Increases to Threshold Reporting Levels 

91. The NOPR found that it is reasonable to increase certain threshold levels for 

reporting specific cost items and invited comment. Specifically, the NOPR proposed to 

increase the threshold reporting levels for (i) page 216 (Construction Work in Progress) 

to $1 million, (ii) pages 232, 233 and 278 (Other Regulatory Assets, Miscellaneous 

Deferred Debits and Other Regulatory Liabilities) to group items featuring an aggregate 

outstanding balance of $100,000 or less, (iii) page 269 (Other Deferred Credits) to 

$100,000, and (iv) pages 352 and 353 (Research and Development) to $50,000.59 

Comments

92. Several commenters support the proposals to increase the threshold reporting 

levels.60 BPA, however, states that Form 1 should contain more information and detail 

rather than less and that no accounts or level of detail should be removed from the current 

Form 1 requirements. Duke and Nevada Companies each proposes alternative thresholds 

as detailed in the following table. 

Page 

No. 

Title of Schedule NOPR Proposal Duke Nevada 

Companies 

1 216 Construction Work in 

Progress-Electric 

$1,000,000 or less may be 

grouped 

Graduated scale 

based on total assets 

Report projects 

$10,000,000 or 

 59 NOPR at P 60. 

60 See AEP, EEI, and FirstEnergy comments. 
Docket No. RM08-5-000 - 49 - 

(Account 107) base more 

2 232 Other Regulatory Assets 

(Account 182.3) 

Amounts less than 

$100,000 may be grouped 

by classes 

$1,000,000, or a 

graduated scale based 

on total asset base 

$1,000,000 

3 233 Miscellaneous Deferred 

Debits (Account 186) 

Amounts less than 

$100,000 may be grouped 

by classes 

$1,000,000, or a 

graduated scale based 

on total asset base 

$1,000,000 

4 269 Other Deferred Credits 

(Account 253) 

Amounts less than 

$100,000 may be grouped 

by classes 

$1,000,000, or a 

graduated scale based 

on total asset base 

$100,000 

5 278 Other Regulatory 

Liabilities (Account 254) 

Amounts less than 

$100,000 may be grouped 

by classes 

$1,000,000, or a 

graduated scale based 

on total asset base 

$1,000,000 

6 353 Research, Development, 

and Demonstration 

Activities 

Group items under 

$50,000 

Graduated scale 

based on total asset 

base 

n.a. 

 

Commission Determination

93. We are not persuaded to adopt the alternate thresholds or graduated reporting 

requirements proposed by some commenters. The Commission believes that the 

proposed thresholds are reasonable and not unduly burdensome. The thresholds balance 

the burden on utilities, and, in fact, in raising the thresholds, lessen the burden while 

continuing to provide meaningful data to this Commission, state commissions, and 

customers that wish to review a utility’s rates. Furthermore, the uniformity of the 

reporting requirement helps ensure that comparable data is available for all major 

utilities. Therefore, we adopt the revised reporting thresholds proposed in the NOPR61

 61 Filers that use Form 1 to meet more specific reporting requirements for 

incentive rate treatment for construction work in progress (CWIP) or other costs must 

continue to meet the obligations arising with the approval of such incentive rates, despite 

these thresholds. Cf., e.g., Potomac-Appalachian Transmission Highline, L.L.C., 

122 FERC ¶ 61,188, at P 155-56 (2008); Trans-Allegheny Interstate Line Co., 119 FERC 

(continued) 
Docket No. RM08-5-000 - 50 - 

and reject the alternative threshold reporting levels and proposals for graduated reporting 

requirements. 

7. Proposed Technical Corrections

94. In response to the NOI, the Commission received a number of suggested technical 

changes and instruction revisions. The Commission listed the suggestions that showed 

merit in the NOPR, Appendix C and invited comment on specific proposals. The 

proposals are reproduced in Appendix B to this Final Rule along with the Commission’s 

responses. The NOPR specifically sought comment on the proposals in Appendix C, 

line 25 (RTO accounting on pages 310-311, 326-327, 332, 397-398), line 32 (measuring 

sales for resale as financial transactions, pages 310 and 326), line 34 (designating 

reporting hours and accounting for financial transactions, page 401A), and line 35 (utility 

of column (b), pages 301 and 326).62 

 

¶ 61,219, at P 45 (2007) (requiring reporting of financial details in Form 1 footnotes as 

condition of approval for CWIP rate incentive). 

62 An additional proposal concerning consistency in distinguishing delivery 

revenues and electricity sales (pages 300-301) has already been addressed in the 

discussion of Other Revenues, above. 
Docket No. RM08-5-000 - 51 - 

Comments

95. SDG&E believes many of the proposed revisions and technical corrections are 

appropriate and provide needed information for rate review without imposing undue

burdens on the filer.63 

96. In regard to the proposal to measure sales for resale as financial transactions 

(pages 310 and 326) on line 32 of Appendix C, APPA supports providing guidelines on 

how to report volume information on the sales for resale and purchased power schedule 

on pages 310 and 326. The proposal asks the Commission to address the reporting of 

financial transactions; APPA believes that the Commission should also address the 

reporting of negative volumes on these schedules. 

Commission Determination

97. The comments received did not offer specifics in response to the NOPR requests 

for comments on the proposals in Appendix C, line 25 (RTO accounting on pages 310-

311, 326-327, 332, 397-398), line 34 (designating reporting hours and accounting for 

financial transactions, page 401A), or line 35 (utility of column (b), pages 301 and 326). 

In addition, with respect to APPA’s proposal to address reporting of negative volumes, 

we decline to adopt such a proposal at this time; APPA has not adequately explained how 

negative volumes arise in purchase or sales transactions. Due to the lack of specific 

proposals, the Commission will not implement the remainder of these changes at this 

 63 BPA and FirstEnergy also generally support the corrections. 
Docket No. RM08-5-000 - 52 - 

time. In addition, for Appendix C, line 32, no commenter provided a specific proposal 

for reporting volume information; consequently, we will not revise our reporting 

requirements at this time. 

8. Additional Technical Revisions

98. EEI’s comments include a number of additional suggested improvements, 

clarifications and corrections to the forms and software: (1) General – on various pages, 

EEI requests the Commission to ensure that all data, descriptions, and amounts roll over 

from one period to the next, to avoid companies having to re-enter the data; (2) General – 

standardize the number formats used to represent credits throughout the form – for 

example, on page 119, column (c), the format is “-50,500,” while in column (d) the 

format is “(50,500);” (3) pages 120-121 – EEI requests a correction to ensure that all 

footnotes print to identify which column is involved when footnotes are added to 

columns (b) or (c); (4) pages 122a-122b and 231– EEI requests the instructions be revised 

to reflect Commission staff guidance that these schedules are to be presented on a yearto-date basis; (5) pages 122a-122b – EEI requests the row heights on the two pages be 

adjusted to be the same, making information easier to follow; (6) pages 329-330 – EEI 

states that the page title should reference account 456.1, not 456; (7) pages 352-353 – 

correct the printing parameters so that the dollars for line 47 print on the same page as the 

description for that line; (8) page 398 – clarify whether a standard unit of measure should 

be applied to Number of Units Sold in column (e), and, if not, how dissimilar units of 
Docket No. RM08-5-000 - 53 - 

measure are to be totaled on line 8; and (9) pages 426-427 –the Form 1 submission 

software (FOSS) should calculate totals for column (f) by Substation Classification. 

99. In addition, EEI supplements the technical revisions proposed in the NOPR and 

requests that the Commission address the following issues:64 (a) the ability to load data 

more cleanly into the software, including Excel data; (b) the ability to copy and paste 

information from Microsoft Word and other native-format documents without losing 

formatting such as underlines, paragraphs, and headers; (c) the ability to print preview for 

Notes to Financials and Important Changes pages; (d) corrections to the “total amount” 

functions in the software, in particular on pages 224, 320-323, 336, 354-355; 

(e) corrections to improper page references, in particular on pages with footnotes; 

(f) corrections to the software’s cross-checking function; and (g) corrections to text on 

various pages of the forms, as noted in NOI comments. 

Commission Determination

100. With respect to EEI’s new suggestions, the Commission confirms: (1) the copy 

forward feature is available for many page schedules, and if additional pages need such a 

feature, filers may make requests to ferconlinesupport@ferc.gov (copying on these pages 

is an option and not mandated); (2) the printing of negative numbers on page 119, column 

(d) will be corrected; (3) the footnote printing issues on pages 120-121 will be addressed; 

 64 AEP supports the software improvements proposed by EEI to enable them to 

load data efficiently into the FERC software. 
Docket No. RM08-5-000 - 54 - 

(4) the instructions on pages 122a, 122b and 231 will be updated; (5) the row heights on 

pages 122a and 122b will be changed, as requested; (6) the page title on pages 329 and 

330 will be corrected (consistent with page 328); and (7) printing parameters on pages 

352-353 will be corrected to address text continuity. As for the two remaining 

suggestions from the list, we clarify: (8) that a standard unit of measure on page 398 is 

not appropriate, because the unit of measure should instead be that used in the filer’s 

billing determinants;65 and (9) consistent with EEI’s request the software already permits 

filers to calculate totals on pages 426-427, column (f) by substation.66 

101. With respect to EEI’s request that the Commission ensure compatibility between 

the Form 1 reporting software and commonly used commercial products such as 

spreadsheet, word processing and accounting software, the Commission is mindful of the 

continual upgrading of commercial software and strives to ensure that the Commission’s 

forms can accommodate the changes. However, we note that several comments 

concerning the eForm software (FOSS) appear to be based on a misunderstanding of the 

software’s capability. The Commission encourages filing companies to contact the 

 65 To facilitate reporting, we will revise the software so that a total can be entered 

on line 8, columns (b) and (e), number of units, if filers wish to use a standard unit of 

measure (otherwise there will be no total). 

66 This feature can be accomplished by entering either “Subtotal” or “Total” as the 

first characters in column (a), which will result in the system calculating values for other 

columns, accordingly. 
Docket No. RM08-5-000 - 55 - 

Commission's Online Support (via email or phone) to resolve technical issues concerning 

the FOSS software. Through calls to Online Support, issues may be addressed in a direct 

and timely manner that is specific to an individual filing company’s concerns. In this 

manner, the Commission, the regulated entities, and the public in general will be best and 

most efficiently served. 

102. As to the specific issues described in the comments, the Commission notes that the 

software incorporates the ability to import data from any spreadsheet program (including 

Excel or Open Office) that is able to export the data using the “dbf” format. Many 

schedules support this capability and also support (but do not require) data roll-over from 

past reports. If importing or data roll-over capability is desired for other pages, filing 

companies should contact ferconlinesupport@ferc.gov. In addition, the software includes 

the capability to import word processing files in the Word format into Form 1, Notes to 

the Financial Statements. It is possible compatibility issues with specific versions of 

word processing software (such as Microsoft Word) may result in some formatting being 

lost. Users experiencing technical difficulties may contact the Commission at 

ferconlinesupport@ferc.gov. The software also features print preview capability and data 

roll-over functions. As for corrections to the “total amount” functions on various pages, 

we have been unable to duplicate the errors referred to in the comments. If a filing 

company is having difficulty with a particular calculation, assistance is available by 

contacting ferconlinesupport@ferc.gov. Finally, steps have been taken to include data 
Docket No. RM08-5-000 - 56 - 

cross-checking in the 2008 Form 1 submission software, and we will make corrections to 

the text on various pages of the forms to address EEI’s suggested editorial changes.67 

E. Miscellaneous

1. Retaining Form 3-Q

103. In the NOPR, we rejected requests that the Commission eliminate Form 3-Q as 

being unnecessary. The Commission believes that the quarterly reports are important 

because they allow more timely evaluations of existing rates and improve the 

transparency and currency of financial information. 

Comments

104. AEP, EEI, and Nevada Companies suggest that the Commission reconsider 

whether the burden of completing the Form 3-Q is warranted when compared to the 

limited value of data it provides. 

Commission Determination

105. We decline to adopt this change for the reasons stated in the NOPR:68 

The Commission believes that the increased frequency of 

financial information provided in Form 3-Q is important. The 

quarterly reports allow for more timely evaluations of 

existing rates and improve the transparency and currency of 

financial information submitted to the Commission. 

 67 Absent reference to particular pages, the Commission is unable to address EEI’s 

remaining request that the Commission correct unspecified improper page references and 

footnotes. 

68 NOPR at P 61. 
Docket No. RM08-5-000 - 57 - 

106. The comments provide no compelling reason to eliminate Form 3-Q. 

2. Confidentiality Concerns

107. In response to NOI comments, the NOPR rejected calls that certain financial data 

should be considered confidential because of concerns raised regarding competitive risks 

and harm to critical infrastructure. The NOPR affirmed the Commission’s commitment 

to maintaining the public availability of financial data filed in Form 1 and other reports 

and found that additional precautions or protection of financial data are not necessary. 

Comments

108. APPA commends the Commission for continuing to improve its collection of 

financial data and for its commitment to maintaining the public availability of the data. 

AEP recommends the Commission reconsider its position and cease to require the release 

of what it characterizes as competitively sensitive commercial information to potential 

competitors that could disadvantage sellers in competitive markets. 

109. EEI encourages the Commission to protect commercially sensitive information, in 

the interest of promoting fair competition and the development of robust competitive 

markets. EEI further encourages the Commission to reconsider its handling of 

commercially sensitive information in the financial forms, to ensure that information is 

not released at a plant or company level if such information may harm companies, either 

in their competition with others or in their negotiations with suppliers. In particular, EEI 

requests, as it has done in previous efforts to revise the reporting requirements that the 
Docket No. RM08-5-000 - 58 - 

Commission cease releasing in discrete form individual generating plant costs and 

operating performance information, and instead release such information only in 

aggregated form that, according to EEI, avoids commercial harm. 

Commission Determination

110. As stated in the NOPR and elsewhere, the Commission remains committed to the 

public availability of cost-of-service data for public utilities. Since 1937, Form 1 data 

have provided a critical component of the Commission’s regulatory program and that of 

its predecessor, the Federal Power Commission.69 While the electricity market is 

changing, regulated public utilities still provide jurisdictional power and transmission 

services for which information is needed in connection with the Commission fulfilling its 

statutory responsibilities. Because transmission service is a critical component in 

electricity service and most transmission rates are cost-based, Form 1 data are critical to 

evaluating the underlying costs of providing transmission service and the resulting rates. 

In addition, Form 1 data provide the basis for many rates for generation service (both 

cost-based and market-based), which may be determined on a unit by unit basis. Making 

this cost data publicly available provides customers with a means to monitor the 

reasonableness of their rates, and thus assists the Commission’s efforts to ensure that 

rates remain just and reasonable. The Commission also has previously reviewed and 

 69 See generally Connecticut Light and Power Co., 2 FPC 853 (1944). 
Docket No. RM08-5-000 - 59 - 

rejected suggestions that it should adopt non-public status for Form 1 data.70 Consistent 

with our long-standing precedent, and in light of the commenters’ failure to convince us 

otherwise, we decline to adopt non-public status for such data here. 

3. Requests to Reconsider Rejected Revisions

111. Duke suggests that the Commission misconstrued its proposal in Docket No. 

RM07-9-000, proposing to eliminate the requirement to report executive officers’ salaries 

on page 104 and argues that the information is not relevant and may be obtained 

elsewhere.71 Duke also renews its objection that the requirement to footnote amounts 

reported in pages 328-330, column (m), is unduly burdensome, because the detail largely 

concerns ancillary services data and filers must insert repetitive footnotes that do little to 

further the user’s understanding of the charges. 

112. Further, Duke believes the Commission misinterpreted Duke’s suggested revisions 

related to pages 422-425. Duke does not request eliminating the pages, but states rather 

that it is proposing a means by which the burden on the filer could be reduced, without 

diminishing the usefulness of the data reported. Duke believes that reporting miles of 

transmission lines by state and legal entity, as well as the totals of the different type of 

 70 See PECO Energy Co., et al., 88 FERC ¶ 61,330 (1999); Consolidated Edison 

Co., 72 FERC ¶ 61,184 (1995). See also Alabama Power Company v. FPC, 511 F.2d 

383, 390-91 (D.C. Cir. 1974) (upholding fuel purchases reporting requirement, and 

rejecting claims that disclosure would lead to bargaining disadvantages in future fuel 

contract negotiations as outweighed by benefits of disclosure). 

71 See NOPR at P 14 (summarizing Duke’s comments responding to the NOI). 
Docket No. RM08-5-000 - 60 - 

supporting structures by voltage, would be sufficient and far less burdensome for filers 

than current practice. Duke questions the claim, cited in the NOPR, stating that pages 

422-425 (as well as pages 426 and 427) provide valuable information on transmission 

lines and substations that allows commenters to track rate base amounts on a facility-byfacility basis. Duke disagrees and questions the necessity of the “to” and “from” level of 

detail.72 According to Duke, the necessary data to calculate transmission rates for RTO 

members that file Form 1 is already largely available in various RTO filings or available 

upon request. Second, Duke states that the “to” and “from” level of detail for filers that 

are not members of RTOs is insignificant because transmission rates for these filers are 

based on average system cost. 

113. Duke proposes that the information contained on pages 426 and 427 be updated in 

its entirety every three years, and that in all other years a filer only be required to report 

additions, retirements and changes to the substations. Duke believes that typically there 

are few changes year-by-year to the amount of information presented on pages 426 and 

427. According to Duke, this change would be beneficial not only to filers, but also to 

users because the changes would be more apparent to users. 

 72 Duke comments at 5. Pages 422-425, col. (a) and (b) provide information on 

transmission lines (132 kV and above), which are designated as running “from” location 

A “to” their destination at location B. Transmission lines below 132 kV are grouped 

together by voltage. 
Docket No. RM08-5-000 - 61 - 

114. APPA supports the Commission’s determination that pages 422–423 and 426–427 

should remain in Form 1. BPA states that Form 1 should contain more information rather 

than less, and that no accounts or level of detail should be removed from the current 

Form 1 requirements. 

Commission Determination

115. The Commission affirms its decision to retain the existing requirements. The 

information is useful to the Commission’s oversight, and is relied upon for the 

monitoring, review and modification of rates. The Commission disagrees that alternate 

approaches of seeking the information, i.e., on request or seeking comparable information 

in various rate, tariff and informational filings, are a substitute for consistent and uniform 

reporting of the data in Form 1. The Form 1 format ensures that the data is available, is 

consistent from year to year and is comparable among filing utilities. In addition, this 

information is valuable because of the increasing demand, and accompanying scrutiny, 

being placed on the transmission grid; there is a continuing need for information to assess 

changes and improvements (both existing and new) to transmission infrastructure. 

4. Requests for Additional Cost Data

116. In the NOPR, we rejected requests for the collection of additional Form 1 data, 

finding that additional detail may be unnecessary. In light of the comments received and 

given the Commission’s experience with reporting requirements, the Commission 

determined that wholesale changes to Form 1 were unnecessary especially in light of the 
Docket No. RM08-5-000 - 62 - 

targeted changes proposed. Therefore, the NOPR did not propose that filers provide a 

cost and revenue study or the type of detailed information needed in a rate case, or 

detailed information on pensions and other employment benefits.73

Comments

a. Pension Information

117. The New York Commission renews its request that the Commission require 

electric utilities to file information regarding pensions and other employee benefits in 

order to assess whether rates are just and reasonable, and states that this need outweighs 

the burden of imposing an incremental reporting requirement upon utilities. The New 

York Commission indicates that the Commission's proposal appears inconsistent with its 

position in Order No. 710. 

b. Transmission Investment

118. The Michigan Commission requests that the Commission clarify whether 

additional detail on new transmission plant in service is required. TAPS proposes that 

the Commission require subdivision of account 353 in order to distinguish account 353 

costs associated with the transmission and generator step-up functions. This requirement 

would apply irrespective of whether a Form 1 filing utility uses a formula rate. TAPS 

states that for the Form 1 to work as a basis for a preliminary rate assessment and serve 

its other rate-regulatory purposes, it should break out the costs of facilities associated 

 73 NOPR at P 35. 
Docket No. RM08-5-000 - 63 - 

with generator step-up transformation and report any methodology used to divide account 

353 between the transformation and transmission functions. According to TAPS, the 

Commission’s accounting practices should reflect rate functionalization for both stated 

and formulaic rates so that customers and regulators may monitor rates and understand 

how the utility functionalizes costs. 

Commission Determination 

119. Contrary to the New York Commission’s view, our decision to rely on existing 

reporting requirements with respect to pension information in this proceeding is not 

inconsistent with our determination in Order No. 710. In that proceeding, which adopted 

changes to our reporting requirements in Form 2 for gas pipelines, we found that 

insufficient information was available because details about the types and costs of 

employee benefits were not readily available due to the pipelines’ participation in multiemployer benefit plans in which they are assigned a portion of the total cost and there 

was flexibility in the way in which information was described in a footnote disclosure.74 

However, in contrast, there was no evidence of a widespread impediment to 

understanding public utilities’ pension obligations. Therefore, we will not impose similar 

reporting requirements here, but instead will rely on our existing reporting requirements.

 74 Order No. 710 at P 38. 
Docket No. RM08-5-000 - 64 - 

120. As stated in the NOPR, we are not persuaded to expand the scope of this 

proceeding, as would be necessary to grant TAPS’ request to revise our accounting 

requirements and provide in this Final Rule the additional information requested. This 

determination is consistent with our holdings elsewhere in this Final Rule with respect to 

requests for additional information related to formula rates and, in particular, 

transmission investment. 

F. Reporting Burden 

121. In the NOPR, the Commission estimated that the proposed new affiliate 

transaction and other information will take respondents 14 hours to collect and report on 

an average annual basis per respondent.75 

Comments

122. EEI comments that, recognizing that reporting does involve substantial costs, the 

Paperwork Reduction Act (PRA) requires federal agencies to strive to minimize the 

reporting burden and avoid duplicative reporting requirements.76 In prior triennial 

reviews, EEI has asked the Commission to review the Forms 1, 1-F, and 3-Q as well as 

other FERC forms to determine if all the information contained in the forms is truly 

 75 NOPR at P 66. 

76 EEI cites 44 U.S.C. 3501, et seq. 
Docket No. RM08-5-000 - 65 - 

needed and whether it is needed in as much detail.77 EEI reiterates that general request 

here and encourages the Commission to minimize the reporting burden to the maximum 

extent possible. 

123. Duke estimates a burden greater than 14 hours to meet the requirements associated 

with the proposed Form 1, page 429 alone; similarly, EEI suggests that compiling the 

proposed affiliate transaction information will take longer than 14 hours.78 MidAmerican 

suggests that the proposed Form 1 affiliate transaction reporting requirement is 

duplicative of existing federal and state affiliate reporting requirements. 

124. SDG&E on the other hand believes that the proposed revisions to the financial 

reporting obligations in the NOPR generally are appropriately balanced to fulfill the 

Commission’s stated goal of obtaining necessary information without imposing undue 

burdens on the filer. 

Commission Determination

125. The Commission’s estimate of the reporting burden refers to the Commission’s 

estimate of the additional amount of time needed to comply with the Form 1 revisions on 

 77 EEI states that the Paperwork Reduction Act requires each agency to undertake 

a triennial review in consultation with the Office of Management and Budget (OMB) to 

demonstrate that information collections are as reasonable and streamlined as possible. 

EEI comments at 2-3. 

78 EEI estimates that the proposed affiliate transaction schedule alone would 

require on the order of 100 to 300 hours per company to compile in the proposed format. 

AEP similarly argues that the affiliate transaction reporting would be voluminous and 

burdensome. 
Docket No. RM08-5-000 - 66 - 

an annual basis, over and above the time needed to prepare the Form 1 under existing 

requirements. Thus, while the Commission is sensitive to filing parties’ individual 

expectations that becoming familiar with the new reporting requirements, compiling and 

reporting certain information may initially take more time than the annual estimate, these 

parties will not need to invest a similar effort in subsequent years. Furthermore, the 

revisions adopted in this Final Rule are not extensive, and largely consist of material that 

is already required to be maintained for other purposes. Therefore, although the initial 

preparation to meet new reporting requirements established in this Final Rule may be 

greater, the Commission believes that the total increase in the time to meet all of the 

Form 1 requirements, existing as well as those adopted in this rule, is not unduly 

burdensome. Furthermore, the Final Rule also relieves some parties of their reporting 

obligations, and lessens the reporting burden for all parties through the increase in the 

threshold reporting requirements for certain items. 

126. FirstEnergy, AEP, MidAmerican, and SDG&E comment on the estimated burden 

of the affiliate transaction reporting requirement; however, they do not offer an 

alternative estimate. Likewise, International Transmission and MidAmerican challenge 

the total 14 hour estimate but fail to offer alternative estimated burden hours. 

127. While Duke cites how they would have to review 187,700 lines of accounting 

related to transactions for its four respondent companies, Duke does not specify what 

such a “review” would entail, nor what the estimated burden would be. Nevada 
Docket No. RM08-5-000 - 67 - 

Companies argue that 40 hours per quarter would be needed or 160 hours annually for the 

affiliate transaction reporting requirement. EEI states it would take anywhere from 100 

to 300 hours, according to its members, to fulfill the affiliated transaction requirement. 

128. In response to Nevada Companies’ burden estimate, the Commission notes that the 

Final Rule only requires a reporting of transactions on an annual basis, not quarterly. 

Therefore, we believe that Nevada Companies’ have overestimated the amount of time 

needed to comply with the requirements. In addition, EEI’s estimate likewise appears to 

be excessive and does not take into account clarifications made in this Final Rule. EEI 

makes several assumptions that have been resolved in a manner that would significantly 

decrease its estimate, including: (1) similar to Nevada Companies, EEI assumes that the 

revised reporting requirements are to be met on a quarterly basis, while the Final Rule 

largely imposes annual reporting requirements;79 (2) EEI assumes that power transactions 

are included, while the Final Rule clarifies, that power transactions are excluded from the 

new page 429 affiliated transaction reporting requirement;80 (3) EEI requests reporting by 

service type category rather than by transaction;81 and (4) EEI’s estimate does not 

account for the $250,000 affiliate transaction reporting threshold of transaction/service 

 79 See EEI comments at 6. 

80 EEI comments at 10. 

81 The Commission does not object so long as the service is ongoing, and is not 

undertaken in response to a particular, non-recurring event. 
Docket No. RM08-5-000 - 68 - 

type adopted in response to comments. In response to concerns raised by the 

commenters, however, the Commission has adjusted its estimate as reflected below. 

VI. Information Collection Statement

129. The collections of information contained in this Final Rule have been submitted to 

the Office of Management and Budget for review under section 3507(d) of the Paperwork 

Reduction Act of 1995;82 the Commission is revising the reporting requirements for 

public utilities and licensees (and for Form 3-Q, also natural gas companies) contained in 

the above financial and operational information collections. 

Title: FERC Form No. 1, “Annual Report of Major Electric Utilities, Licensees, and 

Others”; FERC Form No. 1-F, “Annual Report for Nonmajor Public Utilities and 

Licensees; FERC Form No. 3-Q, “Quarterly Financial Report of Electric Utilities, 

Licensees, and Natural Gas Companies.” 

Action: Final Rule. 

OMB Control Nos. 1902-0021 (Form 1); 1902-0029 (Form 1-F); 1902-0205 (Form 3-Q). 

Respondents: Businesses or other for profit. 

Frequency of responses: Annually and quarterly. 

Necessity of the information: The information collected under the requirements of Part 

141 is essential to the Commission’s fulfilling its statutory responsibilities under the 

 82 44 U.S.C. 3507(d). 
Docket No. RM08-5-000 - 69 - 

FPA. The information collected is used in ratemaking and rate monitoring, for oversight 

of company finances and operations, and for adjudication and regulation. The data 

currently reported in the forms lack the information that would allow the Commission to 

assess and keep pace with changes in the industry and the changes adopted here better 

permit the Commission and the public to evaluate the filers’ jurisdictional rates and 

operations. The additional information to be collected by the Final Rule will increase the 

forms’ usefulness to both the Commission and the public. Without this information, it 

would be more difficult for the Commission and the public to assess costs and operations, 

and thereby ensure that rates are just and reasonable. 

Burden Statement: 

In light of comments from larger transmission-owning public utilities that it may take 

additional time to comply with the new affiliate transaction reporting requirement added 

to Form 1 in this Final Rule, the Commission is revising its information collection 

estimates. Taking into account the comments received, the Commission estimates that on 

average it will take large respondents 28 hours annually to comply with the requirements 

adopted in the Final Rule and smaller respondents 11 hours. There are an estimated 211 

major and 4 nonmajor electric utilities that will be affected by the changes adopted for 

Form 1 in the Final Rule, for a total of 215 respondents.83 Larger utilities with more 

 83 These numbers are based on the most recent filings. 
Docket No. RM08-5-000 - 70 - 

affiliate transactions may face a greater burden in reporting affiliate transaction, other 

revenues and formula rate information. However, the Commission believes that most of 

the additional information required to be reported is already maintained by the utilities. 

The Commission’s estimate has taken into account the commenters’ proposed burden 

estimates. However, the Commission has adjusted these numbers to reflect the 

clarifications made in the Final Rule. Thus, commenters’ proposed affiliated transaction 

burden estimates of 100 to 300 hours are better considered to be 25 to 75 hours, to 

account for the fact that quarterly reporting is not required. Furthermore, because the 

Final Rule does not require reporting of affiliate power transactions on new page 429, the 

affiliate transaction reporting estimate was halved to reflect the Commission’s estimate of 

the transactions to be reported. In addition, the Final Rule adopts the $250,000 threshold 

for affiliate transaction reporting, which will result in a further reduction of the initial 

estimates. The Commission finds that a range of 8 to 20 hours is appropriate to estimate 

the annual burden of affiliate transaction reporting, and, based on its understanding that 

smaller entities will face a lower burden, estimates the typical burden to prepare the 

affiliate transaction schedule to be 12 hours. Assuming a similar burden for the formula 

rate footnote disclosure, the Commission estimates the total burden, including other 

reporting, for the revised Form 1 reporting requirements adopted in this Final Rule to be 

25 hours. The Commission adopts the Form 3-Q burden of one hour as proposed in the 
Docket No. RM08-5-000 - 71 - 

NOPR, since neither the formula rate or affiliate transaction reporting requirements are 

adopted for Form 3-Q. 

The resulting total hours for the following collections of information will be: 

Data Collection 

Form 

Number of 

Respondents 

Change in the 

Number of 

Hours per 

Respondent 

Filing 

Periods 

Change in the 

Total Annual 

Hours 

 (a) (b) (c) (d) (e)=(b)x(c)x(d) 

FERC Form 1 211 25 1 5,275 

FERC Form 3-Q 199 1 3 597 

FERC Form 1-F 4 11 1 44 

Relevant Totals 5,916 

Total Annual Hours for Collection: (Est. Reporting + Recordkeeping (if 

appropriate)) = 5,916 

Information Collection Costs: The Commission estimates the costs to comply with these 

requirements as follows: 

The Commission estimates that the additional hours to complete the additional reporting 

requirements will be divided among a utility’s accounting and internal and outside legal 

services and support staff. The total annualized costs for the information collection is 

$538,356. This number is reached by multiplying the total hours to prepare responses 

(total: 5,916) by an hourly wage estimate of $91 (an average that incorporates senior 

accountant ($50), financial analyst ($40), support staff rates ($25) and legal ($250) 

(salary information source: Bureau of Labor Statistics and market research). These costs 
Docket No. RM08-5-000 - 72 - 

will be spread over 215 utilities, however. On balance, the Commission finds that the 

collection costs will not be unduly burdensome. 

Interested persons may obtain information on the reporting requirements by contacting: 

Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426 

[Attention: Michael Miller, Office of the Chief Information Officer, phone: (202) 502-

8415, fax: (202) 273-0873, email: Michael.Miller@ferc.gov]. Comments concerning the 

collection of information and the associated burden estimates, should be sent to the 

contact listed above and to the Office of Management and Budget, Office of Information 

and Regulatory Affairs, Washington, D.C. 20503 [Attention: Desk Officer for the 

Federal Energy Regulatory Commission, phone (202) 395-7345; fax (202) 395-7285]. 

VII. Environmental Analysis

130. The Commission is required to prepare an Environmental Assessment or an 

Environmental Impact Statement for any action that may have a significant adverse effect 

on the human environment.84 No environmental consideration is needed for the 

promulgation of a rule that addresses information gathering, analysis, and 

dissemination,85 or that addresses accounting.86 This Final Rule involves information 

 84 See Regulations Implementing the National Environmental Policy Act of 1969, 

Order No. 486, FERC Stats. & Regs. ¶ 30,783 (1987). 

85 See 18 CFR 380.4(a)(5). 

86 See 18 CFR 380.4(a)(16). 
Docket No. RM08-5-000 - 73 - 

gathering, analysis, and dissemination, and accounting. Consequently, neither an 

Environmental Impact Statement nor an Environmental Assessment is required. 

VIII. Regulatory Flexibility Act

131. The Regulatory Flexibility Act of 1980 (RFA)87 requires rulemakings to contain 

either a description or analysis of the effect that the rule will have on small entities or a 

certification that the rule will not have a significant economic impact on a substantial 

number of small entities.88 Most utilities regulated by the Commission do not fall within 

the RFA’s definition of a small entity.89 Thus, most utilities to which the rules adopted 

herein apply would not fall within the RFA’s definition of small entities. As noted 

above, the Commission has also sought to alleviate the burden imposed on small entities 

by (a) eliminating a non-jurisdictional utility reporting requirement; (b) accommodating 

non-calendar fiscal year accounting; and (c) increasing the minimum threshold reporting 

levels for certain line-item information. In creating the Form 1 and the Form 1-F, 

moreover, the Commission established two different reporting thresholds so that smaller 

utilities would not be encumbered with having to provide the information necessary to 

comply with the Form 1. Consequently, the Final Rule adopted here will not have a 

significant economic effect on a substantial number of small entities. 

 87 5 U.S.C. 601-12. 

88 Id.

89 5 U.S.C. 601(3). 
Docket No. RM08-5-000 - 74 - 

IX. Document Availability

132. 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 5:00 p.m. Eastern time) at 888 First Street, N.E., Room 2A, 

Washington, D.C. 20426. 

133. From the Commission’s home page on the Internet, this information is available in 

the Commission’s document management system, eLibrary. The full text of this 

document is available on eLibrary in PDF and Microsoft Word format for viewing, 

printing, and/or downloading. To access this document in eLibrary, type the docket 

number excluding the last three digits of this document in the docket number field. 

134. User assistance is available for eLibrary and the Commission’s web site during 

normal business hours. For assistance, please contact FERC Online Support at 1-866-

208-3676 (toll free) or 202-502-6652 or email at ferconlinesupport@ferc.gov, or the 

Public Reference Room at (202) 502-8371, TTY (202) 502-8659. Email at 

public.referenceroom@ferc.gov. 

X. Effective Date and Congressional Notification

135. These regulations are effective for calendar year 2009, i.e., as of January 1, 2009. 

The first report, the Form 3-Q for the first quarter of 2009, will be due in May 2009. The 
Docket No. RM08-5-000 - 75 - 

Commission has determined, with the concurrence of the Administrator of the Office of 

Information and Regulatory Affairs of OMB, that this rule is not a “major rule” as 

defined in section 351 of the Small Business Regulatory Enforcement Fairness Act of 

1996. 

List of subjects

18 CFR Part 41

 Administrative practice and procedures, Electric utilities, Reporting and 

recordkeeping requirements, Uniform System of Accounts 

18 CFR Part 141

 Electric utilities and licensees, Reporting Requirements 

By the Commission. 

( S E A L ) 

Nathaniel J. Davis, Sr., 

Deputy Secretary. 
Docket No. RM08-5-000 - 76 - 

In consideration of the foregoing, the Commission amends Parts 41 and 141 of 

Title 18 of the Code of Federal Regulations, as set forth below: 

PART 41 – ACCOUNTS, RECORDS, MEMORANDA AND DISPOSITION OF 

CONTESTED AUDIT FINDINGS AND PROPOSED REMEDIES

1. The authority citation for part 41 continues to read as follows: 

 Authority: 16 U.S.C. 791a-825r, 2601-2645; 42 U.S.C. 7101-7352. 

2. Section 41.11 is revised to read as follows: 

§ 41.11 Report of certification.

 Each Major and Nonmajor (including those companies classified as nonoperating 

under Part 101, General Instruction 1(A)(3) of this chapter) public utility or licensee 

operating on a calendar year and not classified as Class C or Class D prior to January 1, 

1984 must file with the Commission a letter or report of the independent accountant 

certifying approval, together with or within 30 days after the filing of the Annual Report, 

Form No. 1, covering the subjects and in the form prescribed in the General Instructions 

of the Annual Report. For such utility or licensee operating on a non-calendar fiscal year, 

the letter or report of the independent accountant certifying approval must be filed within 

150 days of the close of the company’s fiscal year; the letter or report must also identify 

which, if any, of the examined schedules do not conform to the Commission’s 

requirements and shall describe the discrepancies that exist. The Commission will not be 
Docket No. RM08-5-000 - 77 - 

bound by a certification of compliance made by an independent accountant pursuant to 

this paragraph. 

PART 141—STATEMENTS AND REPORTS (SCHEDULES) 

3. The authority citation for part 141 is revised to read as follows: 

 Authority: 15 U.S.C. 79; 15 U.S.C. 717-717z; 16 U.S.C. 791a-828c, 2601-2645; 

31 U.S.C. 9701; 42 U.S.C. 7101-7352. 

4. In § 141.1, paragraph (b)(1)(i) is revised to read as follows: 

 § 141.1 FERC Form No. 1, Annual report of Major electric utilities, licensees 

and others. 

* * * * * 

 (b) Filing requirements—(1) Who must file—(i) Generally. Each Major and 

each Nonoperating (formerly designated as Major) electric utility (as defined in part 101 

of Subchapter C of this chapter) and each licensee as defined in section 3 of the Federal 

Power Act (16 U.S.C. 796), including any agency, authority or other legal entity or 

instrumentality engaged in generation, transmission, distribution, or sale of electric 

energy, however produced, throughout the United States and its possessions, having sales 

or transmission service equal to Major as defined above, must prepare and file 

electronically with the Commission the FERC Form 1 pursuant to the General 

Instructions as provided in that form. 

* * * * * 
Docket No. RM08-5-000 - 78 - 

5. In § 141.400, paragraph (b)(1)(i) is revised to read as follows: 

 § 141.400 FERC Form No. 3-Q, Quarterly financial report of electric utilities, 

licensees, and natural gas companies. 

* * * * * 

 (b) Filing requirements—(1) Who must file—(i) Generally. Each electric utility 

and each Nonoperating (formerly designated as Major or Nonmajor) electric utility (as 

defined in part 101 of subchapter C of this chapter) and other entity, i.e., each 

corporation, person, or licensee as defined in section 3 of the Federal Power Act (16 

U.S.C. 792 et seq.), including any agency or instrumentality engaged in generation, 

transmission, distribution, or sale of electric energy, however produced, throughout the 

United States and its possessions, having sales or transmission service must prepare and 

file with the Commission FERC Form No. 3–Q pursuant to the General Instructions set 

out in that form. 

* * * * * 
NOTE: The following Appendices will not be published in the Code of Federal Regulations. 

Appendix A – Revised Form 1 Pages. 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

LIST OF SCHEDULES (Electric Utility) 

Enter in column (c) the terms “none”, “not applicable”, or “NA”, as appropriate, where no information or amounts have been reported for 

certain pages. Omit pages where the respondents are “none”, “not applicable”, or “NA”. 

Line 

No. 

Title of Schedule 

(a) 

Reference 

Page No. 

(b) 

Remarks 

(c) 

1 General Information 101 

2 Control Over Respondent 102 

3 Corporations Controlled by Respondent 103 

4 Officers 104 

5 Directors 105 

6 Information on Formula Rates 106 

7 Important Changes During the Year 108-109 

8 Comparative Balance Sheet 110-113 

9 Statement of Income for the Year 114-117 

10 Statement of Retained Earnings for the Year 118-119 

11 Statement of Cash Flows 120-121 

12 Notes to Financial Statements 122-123 

13 Statement of Accum Comp Income, Comp Income, and Hedging Activities 122(a)(b) 

14 Summary of Utility Plant and Accumulated Provisions for Dep, Amort and Dep 200-201 

15 Nuclear Fuel Materials 202-203 

16 Electric Plant in Service 204-207 

17 Electric Plant Leased to Others 213 

18 Electric Plant Held for Future Use 214 

19 Construction Work in Progress-Electric 216 

20 Accumulated Provision for Depreciation of Electric Utility Plant 219 

21 Investment of Subsidiary Companies 224-225 

22 Materials and Supplies 227 

23 Allowances 228-229 

24 Extraordinary Property Losses 230 

25 Unrecovered Plant and Regulatory Study Costs 230 

26 Transmission Service and Generation Interconnection Study Costs 231 

27 Other Regulatory Assets 232 

28 Miscellaneous Deferred Debits 233 

29 Accumulated Deferred Income Taxes 234 

30 Capital Stock 250-251 

31 Other Paid-in Capital 253 

32 Capital Stock Expense 254 

33 Long-Term Debt 256-257 

34 Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax 261 

35 Taxes Accrued, Prepaid and Charged During the Year 262-263 

36 Accumulated Deferred Investment Tax Credits 266-267 

37 Other Deferred Credits 269 

 

FERC FORM NO. 1 (REV. 12-08) Page 2 

FERC FORM NO. 1-F (REV. 12-08) 

 
Docket No. RM08-5-000 - 80 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

LIST OF SCHEDULES (Electric Utility) 

Enter in column (c) the terms “none”, “not applicable”, or “NA”, as appropriate, where no information or amounts have been reported for 

certain pages. Omit pages where the respondents are “none”, “not applicable”, or “NA”. 

Line 

No. 

Title of Schedule 

(a) 

Reference 

Page No. 

(b) 

Remarks 

(c) 

68 Substations 426-427 

69 Transactions with Associated (Affiliated) Companies 429 

70 Footnote Data 450 

71 Stockholder’s Reports – Check appropriate box: 

 Two copies will be submitted. 

 No annual report to stockholders is prepared. 

 

FERC FORM NO. 1 (REV. 12-08) Page 4 

FERC FORM NO. 1-F (REV. 12-08) 
Docket No. RM08-5-000 - 81 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

Year/Period of Report 

End of Year/Qtr

INFORMATION ON FORMULA RATES 

Does the respondent have formula rates?  Yes 

 No

1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e., Docket No.) 

 accepting the rate(s) or changes in the accepted rate.

FERC Rate Schedule or Tariff Number FERC Proceeding 

 

Does the respondent file with the Commission annual (or more frequent) 

filings containing the inputs to the formula rate(s)? 

 Yes 

 No 

2. If yes, provide a listing of such filings as contained on the Commission’s eLibrary website 

Accession No. Document Date/Filed Date Docket No. Description Formula Rate FERC Rate 

Schedule Number or Tariff 

Number 

 

1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from 

 amounts reported in the Form 1. 

2. The footnote should provide a narrative description explaining how the “rate” (or billing) was derived if different from the reported amount in the 

 Form 1. 

3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items 

 impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. 

4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote. 

Page No(s). Schedule Column Line No 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FERC FORM NO. 1 (NEW 12-08) Page 106
Docket No. RM08-5-000 - 82 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) 

Line 

No. 

Title of Account 

(a) 

Ref. Page 

No. 

(b) 

Current Year 

 End of Quarter/Year 

Balance 

(c) 

Prior Year 

End Balance 

12/31 

(d) 

1 UTILITY PLANT 

2 Utility Plant (101-106, 114) 200-201 

3 Construction Work in Progress (107) 200-201 

4 TOTAL Utility Plant (Enter Total of lines 2 and 3) 

5 (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) 200-201 

6 Net Utility Plant (Enter Total of line 4 less 5 

7 Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1) 202-203 

8 Nuclear Fuel Materials and Assemblies-Stock Account (120.2) 

9 Nuclear Fuel Assemblies in Reactor (120.3) 

10 Spent Nuclear Fuel (120.4) 

11 Nuclear Fuel Under Capital Leases (120.6) 

12 (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) 202-203 

13 Net Nuclear Fuel (Enter Total of lines 7-11 less 12) 

14 Net Utility Plant (Enter Total of lines 6 and 13) 

15 Utility Plant Adjustments (116) 

16 Gas Stored Underground - Noncurrent (117) 

17 OTHER PROPERTY AND INVESTMENTS 

18 Nonutility Property (121) 

19 (Less) Accum. Prov. for Depr. and Amort. (122) 

20 Investments in Associated Companies (123) 

21 Investment in Subsidiary Companies (123.1) 224-225 

22 (For Cost of Account 123.1, See Footnote Page 224, line 42) 

23 Noncurrent Portion of Allowances 228-229 

24 Other Investments (124) 

25 Sinking Funds (125 

26 Depreciation Fund (126) 

27 Amortization Fund - Federal (127) 

28 Other Special Funds (128) 

29 Special Funds (Non Major Only) (129) 

30 Long-Term Portion of Derivative Assets (175) 

31 Long-Term Portion of Derivative Assets – Hedges (176) 

32 TOTAL Other Property and Investments (Lines 18-21 and 23-31) 

33 CURRENT AND ACCRUED ASSETS 

34 Cash and Working Funds (Non-major Only) (130) 

35 Cash (131) 

36 Special Deposits (132-134) 

37 Working Fund (135) 

38 Temporary Cash Investments (136) 

39 Notes Receivable (141) 

40 Customer Accounts Receivable (142) 

41 Other Accounts Receivable (143) 

42 (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) 

43 Notes Receivable from Associated Companies (145) 

44 Accounts Receivable from Assoc. Companies (146) 

45 Fuel Stock (151) 227 

46 Fuel Stock Expenses Undistributed (152) 227 

47 Residuals (Elec) and Extracted Products (153) 227 

48 Plant Materials and Operating Supplies (154) 227 

49 Merchandise (155) 227 

50 Other Materials and Supplies (156) 227 

51 Nuclear Materials Held for Sale (157) 202-

203/307 

 

52 Allowances (158.1 and 158.2) 228-229 

FERC FORM NO. 1 (REV. 12-08) Page 110 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 83 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) (Continued) 

Line 

No. 

Title of Account 

(a) 

Ref. Page 

No. 

(b) 

Current Year 

 End of 

Quarter/Year 

Balance 

(c) 

Prior Year 

End Balance 

12/31 

(d) 

53 (Less) Noncurrent Portion of Allowances 

54 Stores Expense Undistributed (163) 227 

53 Gas Stored Underground - Current (164.1) 

56 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) 

57 Prepayments (165) 

58 Advances for Gas (166-167) 

59 Interest and Dividends Receivable (171) 

60 Rents Receivable (172) 

61 Accrued Utility Revenues (173) 

62 Miscellaneous Current and Accrued Assets (174) 

63 Derivative Instrument Assets (175) 

64 (Less) Long-Term Portion of Derivative Instrument Assets (175) 

65 Derivative Instrument Assets - Hedges (176) 

66 (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176) 

67 Total Current and Accrued Assets (Lines 34 through 66) 

68 DEFERRED DEBITS 

69 Unamortized Debt Expenses (181) 

70 Extraordinary Property Losses (182.1) 230a 

71 Unrecovered Plant and Regulatory Study Costs (182.2) 230b 

72 Other Regulatory Assets (182.3) 232 

73 Prelim. Survey and Investigation Charges (Electric) (183) 

74 Preliminary Natural Gas Survey and Investigation Charges 183.1) 

75 Other Preliminary Survey and Investigation Charges (183.2) 

76 Clearing Accounts (184) 

77 Temporary Facilities (185) 

78 Miscellaneous Deferred Debits (186 233 

79 Def. Losses from Disposition of Utility Plt. (187) 

80 Research, Devel. and Demonstration Expend. (188) 352-353 

81 Unamortized Loss on Reaquired Debt (189) 

82 Accumulated Deferred Income Taxes (190) 234 

83 Unrecovered Purchased Gas Costs (191) 

84 Total Deferred Debits (lines 69 through 83) 

85 TOTAL ASSETS (lines 14-16, 32, 67, and 84) 

FERC FORM NO. 1 (REV. 12-08) Page 111 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 84 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) 

Line 

No. 

Title of Account 

(a) 

Ref. Page 

No. 

(b) 

Current Year 

 End of 

Quarter/Year 

Balance 

(c) 

Prior Year 

End Balance 

12/31 

(d) 

1 PROPRIETARY CAPITAL 

2 Common Stock Issued (201) 250-251 

3 Preferred Stock Issued (204) 250-251 

4 Capital Stock Subscribed (202, 205) 

5 Stock Liability for Conversion (203, 206) 

6 Premium on Capital Stock (207) 

7 Other Paid-In Capital (208-211) 253 

8 Installments Received on Capital Stock (212) 252 

9 (Less) Discount on Capital Stock (213) 254 

10 (Less) Capital Stock Expense (214) 254b 

11 Retained Earnings (215, 215.1, 216) 118-119 

12 Unappropriated Undistributed Subsidiary Earnings (216.1) 118-119 

13 (Less) Reaquired Capital Stock (217) 250-251 

14 Noncorporate Proprietorship (Non-major only) (218) 

15 Accumulated Other Comprehensive Income (219) 122(a)(b) 

16 Total Proprietary Capital (lines 2 through 15) 

17 LONG-TERM DEBT 

18 Bonds (221) 256-257 

19 (Less) Reaquired Bonds (222) 256-257 

20 Advances from Associated Companies (223) 256-257 

21 Other Long-Term Debt (224 256-257 

22 Unamortized Premium on Long-Term Debt (225) 

23 (Less) Unamortized Discount on Long-Term Debt-Debit (226) 

24 Total Long-Term Debt (lines 18 through 23) 

25 OTHER NONCURRENT LIABILITIES 

26 Obligations Under Capital Leases - Noncurrent (227) 

27 Accumulated Provision for Property Insurance (228.1) 

28 Accumulated Provision for Injuries and Damages (228.2) 

29 Accumulated Provision for Pensions and Benefits (228.3) 

30 Accumulated Miscellaneous Operating Provisions (228.4) 

31 Accumulated Provision for Rate Refunds (229) 

32 Long-Term Portion of Derivative Instrument Liabilities 

33 Long-Term Portion of Derivative Instrument Liabilities - Hedges 

34 Asset Retirement Obligations (230) 

35 Total Other Noncurrent Liabilities (lines 26 through 34) 

36 CURRENT AND ACCRUED LIABILITIES 

37 Notes Payable (231) 

38 Accounts Payable (232) 

39 Notes Payable to Associated Companies (233) 

40 Accounts Payable to Associated Companies (234) 

41 Customer Deposits (235) 

42 Taxes Accrued (236) 262-263 

43 Interest Accrued (237) 

44 Dividends Declared (238) 

45 Matured Long-Term Debt (239) 

FERC FORM NO. 1 (REV. 12-08) Page 112 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 85 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

STATEMENT OF INCOME 

Quarterly 

1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column 

 (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing 

 only. 

2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. 

3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in 

 column (k) the quarter to date amounts for other utility function for the current year quarter. 

4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in 

 column (l) the quarter to date amounts for other utility function for the prior year quarter. 

5. If additional columns are needed, place them in a footnote. 

Annual or Quarterly if applicable 

6. Do not report fourth quarter data in columns (e) and (f). 

7. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar 

 manner to a utility department. Spread the amount(s) over lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) 

 totals. 

8. Report amounts in accountant 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. 

9. Report data for lines 8, 10, and 11 for Natural Gas companies using accountants 404.1, 404.2, 404.3, 407.1, and 407.2. 

Line 

No. 

Title of Account 

 (a) 

(Ref.) 

Page No. 

(b)

Total 

Current Year to 

Date Balance for 

Quarter/Year 

(c)

Total 

Prior Year to 

Date Balance for 

Quarter/Year 

(d)

Current 3 months 

Ended 

Quarterly Only 

No 4th Quarter 

(e)

Prior 3 Months 

Ended 

Quarterly Only 

No 4th Quarter 

(f)

1 Utility Operating Income 

2 Operating Revenues (400) 

3 Operating Expenses 

4 Operation Expenses (401) 

5 Maintenance Expenses (402) 

6 Depreciation Expense (403) 

7 Depreciation Expense for Asset Retirement 

Costs (403.1) 

8 Amort. and Depl. of Utility Plant (404-

405) 

9 Amort. of Utility Plant Acq. Adj. (406) 

10 Amort. Property Losses, Unrecov. Plant 

and Regulatory Study Costs (407) 

11 Amort. of Conversion Expenses (407) 

12 Regulatory Debits (407.3) 

13 (Less) Regulatory Credits (407.4) 

14 Taxes Other Than Income Taxes (408.1) 

15 Income Taxes - Federal (409.1) 

16 - Other (409.1) 

17 Provision for Deferred Income Taxes 

(410.1) 

18 (Less) Provision for Deferred Income 

Taxes-Cr. (411.1) 

19 Investment Tax Credit Adj. - Net (411.4) 

20 (Less) Gains from Disp. of Utility Plant 

(411.6) 

21 Losses from Disp. of Utility Plant (411.7) 

22 Losses from Disposition of Allowances 

(411.9) 

23 Losses from Disposition of Allowances 

(411.9) 

24 Accretion Expense (411.10) 

25 TOTAL Utility Operating Expenses (Enter 

Total of lines 4 thru 24) 

26 Net Util Oper Inc (Enter Tot line 2 less 25) 

Carry to Pg117,line 27 

FERC FORM NO. 1 (REV. 12-08) Page 114 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 86 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

STATEMENT OF INCOME FOR THE YEAR (continued) 

Line TOTAL 

No. 

Title of Account 

 (a) 

(Ref.) 

Page No. 

(b) Current 

Year 

(c) 

Previous 

Year 

(d) 

Current 3 

months 

Ended 

Quarterly Only 

No 4th Quarter 

(e)

Prior 3 Months 

Ended 

Quarterly Only 

No 4th Quarter 

(f)

27 Net Utility Operating Income (Carried forward from page 114) 

28 Other Income and Deductions 

29 Other Income 

30 Nonutilty Operating Income 

31 Revenues From Merchandising, Jobbing and Contract Work (415) 

32 (Less) Costs and Exp. of Merchandising, Job. and Contract Work (416) 

33 Revenues From Nonutility Operations (417) 

34 (Less) Expenses of Nonutility Operations (417.1) 

35 Nonoperating Rental Income (418) 

36 Equity in Earnings of Subsidiary Companies (418.1) 119 

37 Interest and Dividend Income (419) 

38 Allowance for Other Funds Used During Construction (419.1) 

39 Miscellaneous Nonoperating Income (421) 

40 Gain on Disposition of Property (421.1) 

41 TOTAL Other Income (Enter Total of lines 31 thru 40) 

42 Other Income Deductions

43 Loss on Disposition of Property (421.2) 

44 Miscellaneous Amortization (425) 

45 Donations (426.1) 

46 Life Insurance (426.2) 

47 Penalties (426.3) 

48 Exp. for Certain Civic, Political and Related Activities (426.4) 

49 Other Deductions (426.5) 

50 TOTAL Other Income Deductions (Total of lines 43 thru 49) 

51 Taxes Applic. to Other Income and Deductions 

52 Taxes Other Than Income Taxes (408.2) 262-263 

53 Income Taxes-Federal (409.2) 262-263 

54 Income Taxes-Other (409.2) 262-263 

55 Provision for Deferred Inc. Taxes (410.2) 234,272-

277 

 

56 (Less) Provision for Deferred Income Taxes-Cr. (411.2) 234,272-

277 

57 Investment Tax Credit Adj.-Net (411.5) 

58 (Less) Investment Tax Credits (420) 

59 TOTAL Taxes on Other Income and Deductions (Total of lines 52-58) 

60 Net Other Income and Deductions (Total of lines 41, 50, 59) 

61 Interest Charges 

62 Interest on Long-Term Debt (427) 

63 Amort. of Debt Disc. and Expense (428) 

64 Amortization of Loss on Reaquired Debt (428.1) 

65 (Less) Amort. of Premium on Debt-Credit (429) 

66 (Less) Amortization of Gain on Reaquired Debt-Credit (429.1) 

67 Interest on Debt to Assoc. Companies (430) 

68 Other Interest Expense (431) 

69 (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) 

70 Net Interest Charges (Total of lines 62 thru 69) 

71 Income Before Extraordinary Items (Total of lines 27, 60 and 70) 

72 Extraordinary Items 

73 Extraordinary Income (434) 

74 (Less) Extraordinary Deductions (435) 

75 Net Extraordinary Items (Total of line 73 less line 74) 

76 Income Taxes-Federal and Other (409.3) 262-263 

77 Extraordinary Items After Taxes (line 75 less line 76) 

78 Net Income (Total of line 71 and 77) 

FERC FORM NO. 1 (REV. 12-08) Page 117 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08)
Docket No. RM08-5-000 - 87 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

 Date of Report 

 (Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES 

1. Report in columns (b), (c), (d), and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. 

2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. 

3. For each category of hedges that have been accounted for as “fair value hedges”, report the accounts affected and the related amounts in a footnote. 

4. Report data on a year-to-date basis. 

Line 

No. 

Item 

(a) 

Unrealized Gains and 

Losses on Availablefor-Sale Securities 

(b) 

Minimum Pension 

Liability Adjustment 

(net amount) 

(c) 

Foreign Currency 

Hedges 

(d) 

Other 

Adjustments 

(e) 

1 Balance of Account 219 at Beginning of 

Preceding Year 

 

2 Preceding Qtr/Yr to Date Reclassifications 

from Acct 219 to Net Income 

3 Preceding Qtr/Yr to Date Changes in Fair 

Value 

4 Total (lines 2 and 3) 

5 Balance of Account 219 at End of 

Preceding Qtr/Yr 

6 Balance of Account 219 at Beginning of 

Current Year 

7 Current Qrt/Yr to Date Reclassifications 

from Act 219 to Net Income 

8 Current Qrt/Yr to Date Changes in Fair 

Value 

9 Total (lines 7 and 8) 

10 Balance of Account 219 at End of Current 

Qrt/Yr 

 

FERC FORM NO. 1 (REV. 12-08) Page 122a 

FERC FORM NO. 1-F (REV.12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 88 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS 

FOR DEPRECIATION, AMORTIZATION AND DEPLETION 

Report in column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other 

(specify) and in column (h) common function. 

Line 

No. Classification 

(a) 

Total Company for the Current 

Year/Quarter Ended 

(b) 

Electric 

(c) 

1 Utility Plant 

2 In Service 

3 Plant in Service (Classified) 

4 Property Under Capital Leases 

5 Plant Purchased or Sold 

6 Completed Construction not Classified 

7 Experimental Plant Unclassified 

8 Total (3 thru 7 

9 Leased to Others 

10 Held for Future Use 

11 Construction Work in Progress 

12 Acquisition Adjustments 

13 Total Utility Plant (8 thru 12) 

14 Accum Prov for Depr, Amort, and Depl 

15 Net Utility Plant (13 less 14) 

16 Detail of Accum Prov for Depr, Amort and Depl 

17 In Service: 

18 Depreciation 

19 Amort and Depl of Producing Nat Gas Land/Land Right 

20 Amort of Underground Storage Land/Land Rights 

21 Amort of Other Utility Plant 

22 Total In Service (18 thru 21) 

23 Leased to Others 

24 Depreciation 

25 Amortization and Depletion 

26 Total Leased to Others (24 and 25) 

27 Held for Future Use 

28 Depreciation 

29 Amortization 

30 Total Held for Future Use (28 and 29) 

31 Abandonment of Leases (Natural Gas) 

32 Amort of Plant Acquisition Adj 

33 Total Accum Prov (equals 14) (22,26,30,31,32) 

FERC FORM NO. 1 (REV. 12-08) Page 200 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 89 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

CONSTRUCTION WORK IN PROGRESS - ELECTRIC (Account 10 7) 

1. Report descriptions and balances at end of year for projects in process of construction (107). 

2. Show items relating to “research, development, and demonstration” projects last, under a caption Research, Development, and 

 Demonstrating (see Account 107 of the Uniform System of Accounts). 

3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000 whichever is less) may be grouped. 

Line 

No. 

Description of Project 

(a) 

Construction work in progress – 

Electric (Account 107) 

(b) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

39 

40 

41 

42 

43 

44 

45 

46 

47 

48 

49 

50 

51 

52 

 

FERC FORM NO. 1 (REV. 12-08) Page 216
Docket No. RM08-5-000 - 90 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 

Year/Period of Report 

End of Year/Qtr

ALLOWANCES (Accounts 158.1 and 158.2) 

1. Report the particulars (details) called for concerning allowances. 

2. Report all acquisitions of allowances at cost. 

3. Report allowances in accordance with the weighted average cost allocation method and other accounting as prescribed by General 

Instruction No. 21 in the Uniform System of Accounts. 

4. Report the allowance transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), 

allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining 

succeeding years in columns (j)-(k). 

5. Report on Lines 4 and 50, the Environmental Protection Agency (EPA) issued allowances. Report withheld portions on Lines 36-

40 and Lines 82-86. 

Line Current Year 2010 

No. 

SO2 Allowances Inventory 

(Account 158.1) 

(a) 

No. 

(b) 

Amount 

(c) 

No. 

(d) 

Amount 

(e) 

1 Balance-Beginning of Year 

2 

3 Acquired During Year: 

4 Issued (Less Withheld Allow) 

5 Returned by EPA 

6 

7 

8 Purchases/Transfers: 

9 Other Purchases-See notes 

10 

11 

12 

13 

14 

15 Total 

16 

17 Relinquished During Year: 

18 Charges to Account 509 

19 Other: 

20 

21 Cost of Sales/Transfers: 

22 Other Sales-See notes 

23 

24 

25 

26 

27 

28 Total 

29 Balance-End of Year 

30 

31 Sales: 

32 Net Sales Proceeds (Assoc. Co.) 

33 Net Sales Proceeds (Other) 

34 Gains 

35 Losses 

 Allowances Withheld (Acct 158.2) 

36 Balance-Beginning of Year 

37 Add: Withheld by EPA 

38 Deduct: Returned by EPA 

39 Cost of Sales 

40 Balance-End of Year 

41 

42 Sales: 

43 Net Sales Proceeds (Assoc. Co.) 

44 Net Sales Proceeds (Other) 

45 Gains 

46 Losses 

FERC FORM NO. 1 (REV. 12-08) Page 228a 

FERC FORM NO. 1-F (REV. 12-08)
Docket No. RM08-5-000 - 91 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 

Year/Period of Report 

End of Year/Qtr

ALLOWANCES (Accounts 158.1 and 158.2) (Continued) 

Line Current Year 2010 

No. 

NOx Allowances Inventory 

(Account 158.1) 

(a) 

No. 

(b) 

Amount 

(c) 

No. 

(d) 

Amount 

(e) 

47 Balance-Beginning of Year 

48 

49 Acquired During Year: 

50 Issued (Less Withheld Allow) 

51 Returned by EPA 

52 

53 

54 Purchases/Transfers: 

55 Other Purchases-See notes 

56 

57 

58 

59 

60 

61 Total 

62 

63 Relinquished During Year: 

64 Charges to Account 509 

65 Other: 

66 

67 Cost of Sales/Transfers: 

68 Other Sales-See notes 

69 

70 

71 

72 

73 

74 Total 

75 Balance-End of Year 

76 

77 Sales: 

78 Net Sales Proceeds (Assoc. Co.) 

79 Net Sales Proceeds (Other) 

80 Gains 

81 Losses 

 Allowances Withheld (Acct 158.2) 

82 Balance-Beginning of Year 

83 Add: Withheld by EPA 

84 Deduct: Returned by EPA 

85 Cost of Sales 

86 Balance-End of Year 

87 

88 Sales: 

89 Net Sales Proceeds (Assoc. Co.) 

90 Net Sales Proceeds (Other) 

91 Gains 

92 Losses 

FERC FORM NO. 1 (REV. 12-08) Page 228b 

FERC FORM NO. 1-F (REV. 12-08) 
Docket No. RM08-5-000 - 92 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 

Year/Period of Report 

End of Year/Qtr

ALLOWANCES (Accounts 158.1 and 158.2) 

6. Report on Lines 5 and 51 allowances returned by the EPA. Report on Lines 39 and 76 the EPA sales of the withheld allowances. 

Report on Lines 43-46 and 89-92 the net proceeds and gains/losses resulting from the EPA sale or auction of the withheld allowances. 

7. Report on Lines 8-14 and 54-60 the names of vendors/transferors of allowances acquired and identify associated companies (See 

“associated company” under “Definitions” in the Uniform System of Accounts). 

8. Report on Lines 22-27 and 68-73 the names of purchasers/transferees of allowances disposed of and identify associated companies. 

9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales transfers. 

10. Report on Lines 32-35, 78-81, 43-46 and 89-92 the net sales proceeds and gains or losses from allowances sales. 

2011 2012 Future Years Totals 

No. 

(f) 

Amount 

(g) 

No. 

(h) 

Amount 

(i) 

No. 

(j) 

Amount 

(k) 

No. 

(l) 

Amount 

(m) 

Line 

No. 

 1 

2 

3 

 4 

 5 

6 

7 

 8 

 9 

 10 

 11 

 12 

 13 

 14 

 15 

16 

17 

 18 

19 

 20 

21 

 22 

 23 

 24 

 25 

 26 

 27 

 28 

 29 

30 

31 

 32 

 33 

 34 

 35 

 36 

 37 

 38 

 39 

 40 

41 

42 

 43 

 44 

 45 

 46 

FERC FORM NO. 1 (REV. 12-08) Page 229a 

FERC FORM NO. 1-F (REV. 12-08)
Docket No. RM08-5-000 - 93 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 

Year/Period of Report 

End of Year/Qtr

ALLOWANCES (Accounts 158.1 and 158.2) (Continued) 

2011 2012 Future Years Totals 

No. 

(f) 

Amount 

(g) 

No. 

(h) 

Amount 

(i) 

No. 

(j) 

Amount 

(k) 

No. 

(l) 

Amount 

(m) 

Line 

No. 

 47 

48 

49 

 50 

 51 

52 

53 

 54 

 55 

 56 

 57 

 58 

 59 

 60 

 61 

62 

63 

 64 

65 

 66 

67 

 68 

 69 

 70 

 71 

 72 

 73 

 74 

 75 

76 

77 

 78 

 79 

 80 

 81 

 82 

 83 

 84 

 85 

 86 

87 

88 

 89 

 90 

 91 

 92 

FERC FORM NO. 1 (REV. 12-08) Page 229b 

FERC FORM NO. 1-F (REV. 12-08) 
Docket No. RM08-5-000 - 94 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo., Da., Yr.) 

Year/Period of Report 

End of Year/Qtr

TRANSMISSION SERVICE AND GENERATION INTERCONNECTION STUDY COSTS 

1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator 

 interconnection studies. 

2. List each study separately. 

3. Report in column (a) provide the name of the study. 

4. Report in column (b) the cost incurred to perform the study at the end of period. 

5. Report in column (c) the account charged with the cost of the study. 

6. Report in column (d) the amounts received for reimbursement of the study costs at end of period. 

7. Report in column (e) the account credited with the reimbursement received for performing the study. 

8. Report data on a year-to-date basis. 

Line 

No. 

Description 

(a) 

Costs Incurred During 

Period 

(b) 

Account Charged 

(c) 

Reimbursements 

Received During the Period 

(d) 

Account 

Credited 

With 

Reimbursement 

(e) 

Transmission Studies 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

Generation Studies 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

FERC FORM NO. 1 (REV. 12-08) Page 231 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 95 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

OTHER REGULATORY ASSETS (Account 182.3) 

1. Report the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. 

2. Minor items (5% of the Balance at the End of the Year for Account 182.3 or amounts less than $100,000 whichever is less) may be grouped 

 by classes. 

3. For Regulatory Liabilities being amortized, show period of amortization. 

CREDITS 

Line 

No. 

Description and 

Purpose of Other 

Regulatory Assets 

(a) 

Balance at 

Beginning 

Current 

Quarter/Year 

(b) 

Debits 

(c) Written off 

During 

Quarter/Year 

Account Charged 

(d) 

Written off 

During the 

Period 

(e) 

Balance at End of Current 

Quarter/Year 

(f) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

Total 

FERC FORM NO. 1 (REV.12-08) Page 232 

FERC FORM NO. 1-F (REV.12-08) 

FERC FORM NO. 3-Q (REV.12-08) 
Docket No. RM08-5-000 - 96 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

MISCELLANEOUS DEFERRED DEBITS (Account 186) 

1. Report the particulars (details) called for concerning miscellaneous deferred debits. 

2. For any deferred debit being amortized, show period of amortization in column (a). 

3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by 

 classes. 

Line 

No. 

Title of Account 

 (a) 

(Ref.) 

Page No. 

(b)

Total 

Current Year to 

Date Balance for 

Quarter/Year 

(c)

Total 

Prior Year to 

Date Balance for 

Quarter/Year 

(d)

Current 3 months 

Ended 

Quarterly Only 

No 4th Quarter 

(e)

Prior 3 Months 

Ended 

Quarterly Only 

No 4th Quarter 

(f)

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

39 

40 

41 

42 

43 

44 

45 

46 

47 

48 

49 

FERC FORM NO. 1 (REV. 12-08) Page 233 
Docket No. RM08-5-000 - 97 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

OTHER DEERRED CREDITS (Account 253) 

1. Report the particulars (details) called for concerning other deferred credits. 

2. For any deferred credit being amortized, show the period of amortization. 

3. Minor items (5% of the Balance at the End of the Year for Account 253 or amounts less than $100,000, whichever is less) may be grouped by 

 classes. 

Line No. Description and Other CREDITS 

Deferred Credits 

(a) 

Balance at 

Beginning Year 

(b) Contra Account 

(c) 

Amount 

(d) 

Credits 

(e) 

Balance at End 

of Year 

(f) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

39 

40 

41 

42 

43 

44 

45 

46 

47 

FERC FORM NO. 1 (REV.12-08) Page 269 
Docket No. RM08-5-000 - 98 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

Other Regulatory Liabilities (Account 254) 

1. Report the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. 

2. Minor items (5% of the Balance at the End of the Year for Account 254 or amounts less than $100,000, whichever is less) may be grouped by 

 classes. 

3. For Regulatory Liabilities being amortized, show period of amortization. 

Line DEBITS 

No. 

Description and Purpose of 

Other Regulatory Assets 

(a) 

Balance at 

Beginning 

Current 

Quarter/Year 

(b) 

Account Credited 

(c) 

Amount 

(d) 

Credits 

(e) 

Balance at End 

of Current 

Quarter/Year 

(f) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

Total 

FERC FORM NO. 1 (REV. 12-08) Page 278 

FERC FORM NO. 1-F (REV.12-08) 

FERC FORM NO. 3-Q (REV.12-08) 
Docket No. RM08-5-000 - 99 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

ELECTRIC OPERATING REVENUES (Account 400) 

1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). 

 Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. 

2. Report operating revenues for each prescribed account, and manufactured gas revenues in total. 

3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where 

 separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average 

 number of customers means the average of twelve figures at the close of each month. 

4. If increases or decreases from previous period (columns (c), (e), and (g)), are not derived from previously reported figures, explain any 

 inconsistencies in a footnote. 

5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. 

Line 

No. 

Title of Account 

(a) 

Operating Revenues Year to Date 

Quarterly/Annual 

(b) 

Operating Revenues 

Previous year (no 

Quarterly) 

(c) 

1 Sales of Electricity 

2 (440) Residential Sales 

3 (442) Commercial and Industrial Sales 

4 Small (or Comm.) (See Instruction 4) 

5 Large (or Ind.) (See Instruction 4) 

6 (444) Public Street and Highway Lighting 

7 (445) Other Sales to Public Authorities 

8 (446) Sales to Railroads and Railways 

9 (448) Interdepartmental Sales 

10 TOTAL Sales to Ultimate Consumers 

11 (447) Sales for Resale 

12 TOTAL Sales of Electricity 

13 (Less) (449.1) Provision for Rate Returns 

14 TOTAL Revenues Net of Prov. for Refunds 

15 Other Operating Revenues 

16 (450) Forfeited Discounts 

17 (451) Miscellaneous Service Revenues 

18 (453) Sales of Water and Water Power 

19 (454) Rent from Electric Property 

20 (455) Interdepartmental Rents 

21 (456) Other Electric Revenues 

22 (456.1) Revenues from Transmission of Electricity of Others 

23 (457.1) Regional Control Service Revenues 

24 (457.2) Miscellaneous Revenues 

25 

26 TOTAL Other Operating Revenues 

27 TOTAL Electric Operating Revenues 

FERC FORM NO. 1 (REV. 12-08) Page 300 

FERC FORM NO. 1-F (REV.12-08) 

FERC FORM NO. 3-Q (REV.12-08) 
Docket No. RM08-5-000 - 100 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (continued) 

(Including transactions referred to as “wheeling” 

5. In column (e), identify the FERC Rate Schedule of Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as 

 identified in column (d), is provided. 

6. Report receipt and delivery locations for all single contract path, “point to point” transmission service. In column (f), report the designation for the substation, or other 

 appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate 

 identification for where energy was delivered as specified in the contract. 

7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in 

 megawatts. Footnote any demand not stated on a megawatts basis and explain. 

8. Report in column (i) and (j) the total megawatt hours received and delivered. 

FERC Rate TRANSFER OF ENERGY 

Schedule of 

Tariff Number

(e)

Point of Receipt 

(Substation or Other 

Designation) 

(f) 

Point of Delivery 

(Substation or Other 

Designation) 

(g) 

Billing 

Demand 

(MW) 

(h) 

Megawatt Hours 

Received 

(i) 

Megawatt Hours 

Delivered 

(j) 

Line 

No. 

 1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

FERC FORM NO. 1 (REV. 6-08) Page 329 

FERC FORM NO. 1-F (REV. 6-08) 

FERC FORM NO. 3-Q (REV. 6-08) 
Docket No. RM08-5-000 - 101 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (continued) 

(Including transactions referred to as “wheeling” 

9. Report in column (k) through (n), the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing 

 demand reported in column (h). In column (l), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total 

 revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in 

 column (m). Report in column (n) the total charge shown on bills rendered to the entity listed in column (a). If no monetary settlement was made, enter zero (11011) 

 in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 

10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 

 16 and 17, respectively. 

11. Footnote entries and provide explanations following all required data. 

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS 

Demand Charges 

($) 

(k) 

Energy Charges 

($) 

(l) 

(Other Charges) 

($) 

(m) 

Total Revenues ($) 

(k+l+m) 

(n) 

Line 

No. 

 1 

 2 

 3 

 4 

 5 

 6 

 7 

 8 

 9 

 10 

 11 

 12 

 13 

 14 

 15 

 16 

 17 

 18 

 19 

 20 

 21 

 22 

 23 

 24 

 25 

 26 

 27 

 28 

 29 

 30 

 31 

 32 

 33 

 

FERC FORM NO. 1 (REV. 6-08) Page 330 

FERC FORM NO. 1-F (REV. 6-08) 

FERC FORM NO. 3-Q (REV. 6-08) 
Docket No. RM08-5-000 - 102 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565) 

(Including transactions referred to as “wheeling”) 

1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and 

 others for the quarter. 

2. Report in column (a) each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not 

 truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as 

 necessary to report all companies or public authorities that provided transmission service for the quarter reported. 

3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: 

 FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Reservations. OLF – Other Service, and OS – Other 

 Transmission Service. See General Instructions for definitions of statistical classifications. 

4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. 

5. Report in column (e), (f), and (g) expenses as shown in bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) 

 energy charges related to the amount of energy transferred. In column (g) report the total of all components of the amount shown in column (g). Report in column 

 (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the 

 nature of the non-monetary settlement. 

6. Enter “TOTAL” in column (a) as the last line. 

7. Footnote entries and provide explanations following all required data. 

 

TRANSFER OF 

ENERGY 

Line EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS 

No. 

Name of Company or Public 

Authority (Footnote Affiliations) 

(a) 

Statistical 

Classification 

(b) Megawatthours 

Received

(c) 

Megawatthours 

Delivered 

(d) 

Demand 

 Charges 

($) 

(e) 

Energy 

Charges 

($) 

(f) 

Other 

Charges 

($) 

(g) 

Total Cost of 

Transmission 

($) 

(h) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

 TOTAL 

FERC FORM NO. 1 (REV. 12-08) Page 332 

FERC FORM NO. 1-F (REV. 12-08) 

FERC FORM NO. 3-Q (REV. 12-08) 
Docket No. RM08-5-000 - 103 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES 

1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration 

 (R, D, and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly- 

 sponsored projects. (Identify recipient regardless of affiliation.). For any R, D and D work carried with others, show separately the 

 respondent’s cost for the year and cost chargeable to others (See definition of research, development, and demonstration in the Uniform 

 System of Accounts). 

2. Indicate in column (a) the applicable classification, as shown below: 

Classifications: 

A. Electric R, D and D Performed Internally: a. Overhead 

 (1) Generation b. Underground 

 a. Hydroelectric (3) Distribution 

 i.. Recreation fish and wildlife (4) Regional Transmission and Market Operation 

 ii. Other hydroelectric (5) Environment (other than equipment) 

 b. Fossil-fuel steam (6) Other (Classify and include items in excess of $50,000.) 

 c. Internal combustion or gas turbine (7) Total Cost Incurred 

 d. Nuclear B. Electric R, DandD Performed Externally: 

 e. Unconventional generation (1) Research Support to the Electrical Research Council or the 

 f. Siting and heat rejection Electric Power Research Institute 

 (2) Transmission 

Line 

No. 

Classification 

(a) 

Description 

(b) 

1 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

 

FERC FORM NO. 1 (REV.12-08) Page 352 
Docket No. RM08-5-000 - 104 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES (Continued) 

 (2) Research Support to Edison Electric Institute 

 (3) Research Support to Nuclear Power Groups 

 (4) Research Support to Others (Classify) 

 (5) Total Cost Incurred 

3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing 

 $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, 

 insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, 

 (A (6) and B (4)) classify items by type of R, D and D activity. 

4. Show in column (e) the account number charged with expensed during the year or the account to which amounts were capitalized during the 

 year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column 

 (e). 

5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, 

 Development, and Demonstration Expenditures, Outstanding at the end of the year. 

6. If costs have not been segregated for R, D&D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts 

 identified by “Est.” 

7. Report separately research and related testing facilities operated by the respondent. 

Costs Incurred Internally AMOUNTS CHARGED IN CURRENT YEAR 

Current Year 

(c) 

Costs Incurred Externally 

Current Year 

(d) 

Account 

(e) 

Amount 

(f) 

Unamortized 

Accumulation

(g) 

Line 

No. 

 1 

 2 

 3 

 4 

 5 

 6 

 7 

 8 

 9 

 10 

 11 

 12 

 13 

 14 

 15 

 16 

 17 

 18 

 19 

 20 

 21 

 22 

 23 

 24 

 25 

 26 

 27 

 28 

 29 

 30 

 31 

 32 

 33 

 34 

 35 

 36 

 

FERC FORM NO. 1 (REV.12-08) Page 353 
Docket No. RM08-5-000 - 105 - 

Name of Respondent This Report Is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

MONTHLY PEAKS AND OUTPUT 

1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the 

 required information for each non-integrated system. 

2. Report in column (b) by month the system’s output in Megawatt hours for each month. 

3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the 

 sales. 

4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. 

5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d). 

NAME OF SYSTEM: 

Line Monthly Peak 

No. 

Month 

(a) 

Total Monthly Energy 

(b) 

Monthly NonRequirements Sales 

for Resale and 

Associated Losses 

(c) 

Megawatts (See inst. 4) 

(d) 

Day of Month 

(e) 

Hour 

(f) 

29 January 

30 February 

31 March 

32 April 

33 May 

34 June 

35 July 

36 August 

37 September 

38 October 

39 November 

40 December 

41 TOTAL 

 

FERC FORM NO. 1 (REV. 12-08) Page 401b 

FERC FORM NO. 1-F (REV.12-08) 
Docket No. RM08-5-000 - 106 - 

Name of Respondent This Report is: 

(1)  An Original 

(2)  A Resubmission 

Date of Report 

(Mo, Da, Yr) 

 / / 

Year/Period of Report 

End of Year/Qtr

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES 

1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) 

 companies. 

2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to 

 an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not 

 attempt to include or aggregate amounts in a nonspecific category such as “general”. 

3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote. 

 

Line 

No. 

Description of the Non-Power Good or Service 

(a) 

Name of 

Associated/Affiliated 

Company 

(b) 

Account 

Charged or 

Credited 

(c) 

Amount 

Charged or Credited 

(d) 

1 Non-power Goods or Services Provided by Affiliated Company 

2 

3 

4 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

18 

19 

20 Non-power Goods or Services Provided for Affiliated Company 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

39 

40 

41 

42 

43 

44 

FERC Form No. 1 (New) Page 429 

FERC Form No. 1-F (New)
Docket No. RM08-5-000 - 107 - 

Appendix B - List of Proposed Technical Changes and Responses. 

 Name Comment Commission Response 

1 

EEI 

and 

NYISO 

The software’s cross-checking function has not been 

functional for some time, requiring companies to 

perform an additional level of review and verification. 

The data cross-checking function 

is being updated for the 2008 

reporting year. 

2 Duke 

Column width cannot be altered to make dollar input 

fit and be readable. This occurred on Form 1, pages 

120-121, Statement of Cash Flows, line 44, column 

(b). 

This problem could not be 

replicated and may be a function 

of the user’s printer setup. 

Twelve readable digits can be 

added. 

3 EEI 

Page 114, Instruction # 1 – Should it read report in 

column (e) the balance for the reporting quarter and 

in column (f) the balance for the same three-month 

period for the prior year, rather than column (d) and 

column (e)? The instruction appears to be a column 

off. 

The instructions are being 

revised. 

4 EEI 

Page 114, Instruction # 2 – Should it read report in 

column (g) the quarter-to-date amounts for electric 

utility function; in column (i) the quarter-to-date 

amounts for gas utility, and in column (k) the quarterto-date amounts for other utility function for the 

current year’s quarter, rather than columns (f), (h), 

and(j). The instruction appears to be a column off. 

The instructions are being 

revised. 

5 EEI 

Page 114, Instruction # 3 – Should it read report in 

column (h) the quarter-to-date amounts for electric 

utility function; in column (j) the quarter-to-date 

amounts for gas utility; and in column (l) the quarterto-date amounts for other utility function for the prior 

year quarter, rather than columns (g), (i), and (k)? 

The instruction appears to be a column off. 

The instructions are being 

revised. 

6 EEI Page 200 – Should column (h) be for Common rather 

than column (f), as referenced in instructions? The instructions are being 

revised. 

7 EEI Page 205 – Instruction 9 cuts off, as well as anything 

after that. The correction is being made. 

8 EEI 

Page 401b – The instructions refer to lines 2 through 

6, but there are no such lines on this page. The 

instructions should refer to columns (b) through (f). The correction is being made. 

9 EEI 

Page 110, Line 15 has a reference page to 122. 

There is no page 122; it is “Intentionally Left Blank.” 

Why is the page referenced on the Balance Sheet? The reference is being corrected. 

10 EEI Page 111, Line 70 should reference page 230a, not 

page 230. The reference is being revised. 

11 EEI Page 111, line 72 should reference page 230b, not The reference is being revised. 
Docket No. RM08-5-000 - 108 - 

page 230. 

12 EEI Page 112, lines 4-6 and 8 reference page 252. There 

is no page 252. Why is it referenced? The reference is being corrected. 

12

-a 

EEI Page 112, line 10 should reference page 254b, not 

page 254. The reference is being corrected. 

13 EEI Page 117, lines 43-44 and 66-67 reference page 340. 

There is no page 340. Why is it referenced? The reference is being corrected. 

14 EEI 

Pages 122(a) and (b) – These pages follow the notes, 

but should come before the notes according to the 

page number order. 

The Comparative Balance Sheet, 

Statement of Income, Statement 

of Retained Earnings, Statement 

of Cash Flows, together with the 

Notes to the Financial 

Statements are part of the basic 

financial statements. They are 

all subject to the CPA 

Certification Statement 

requirements. Since the 

Statement of Comprehensive 

Income, pages 122(a) and (b), is 

not a basic financial statement it 

follows these schedules. 

15 EEI 

On many pages of the Form 1, the footnotes contain 

improper page references or appear on the wrong 

page. Each of the pages that contains footnotes 

shows page 450.1 on the bottom, regardless of the 

actual page number. 

There are no known issues. 

Users experiencing problems 

may contact 

ferconlinesupport@ferc.gov 

Page 450.1 is being revised to 

say “footnote” 

16 Duke Printed hard copies from the software do not always 

match what is seen on screen. 

The printed hard copy should 

match what is seen on the 

screen. If the user finds a 

difference between the two, 

please contact 

ferconlinesupport@ferc.gov

17 EEI 

Page 399 – Grayed-out items (where no data should 

appear) get populated with subtotals or random 

figures that do not appear to be derived from a 

formula or calculation. Companies have to black 

them out with a marker when submitting the forms for 

printing. Can this be deleted or corrected? 

In column (d), Lines 4, 8 and 12 

appear to show subtotals where 

amounts are grayed-out and are 

being corrected. 

18 EEI Duplicate pages often print. Is it possible to make 

changes to prevent this? 

Individual users may experience 

problems because their networks 

or operating systems may 

interfere with receiving a 

software update. Users 

experiencing this problem should 

contact 

ferconlinesupport@ferc.gov

19 Duke There have been instances when footnotes have 

been added to pages and disappear upon later return 

While individual users might 

experience this problem, it is not 
Docket No. RM08-5-000 - 109 - 

to the page. software related. Users 

experiencing problems may 

contact 

ferconlinesupport@ferc.gov

20 Duke At times, filers have not been able to save changes to 

the forms when using the save function. 

While individual users might 

experience this problem, it is not 

software related. Users 

experiencing problems should 

contact 

ferconlinesupport@ferc.gov

21 EEI 

When companies enter information into FOSS, they 

find in some cases that the information is inaccurately 

totaled, incorrectly displayed on the screen, or 

wrongly printed. 

The problem could not be 

replicated. Users experiencing 

problems should contact 

ferconlinesupport@ferc.gov

22 EEI 

EEI members have experienced a number of 

problems with the current FERC financial form 

software, Version 5.19.0 of FOSS. 

The current version of the Form 

1 Submission Software is 

Version 5.22.0. 

User experiencing problems 

should contact 

ferconlinesupport@ferc.gov

23 NYISO 

The “data cross-check” feature used in the 

Commission’s reporting software has not always 

functioned correctly. 

The data cross-checking function 

is being updated for the 2008 

reporting year. 

24 EEI 

Page 332 – In the Transfer of Energy section column 

headings, the word megawatt is misspelled as 

“magawatt.” 

The correction is being made. 

25 

Wisc. 

Electric 

Power 

Co. 

Wisconsin Electric suggests that the instructions to all 

pages should be updated to include regional 

transmission organization (“RTO”) accounting and 

reporting requirements. Specifically, pages 310-311, 

326-327, 332, 397-398 should receive this update. 

The instructions on these pages should also be 

enhanced to provide proper RTO MWh netting and 

reporting to meet FERC requirements. 

We are reviewing the instructions 

to these pages in order to update 

them as appropriate in a future 

update to Form 1. 

26 NYISO 

The Financial Forms do not provide clarity as to what 

level of reporting information is required for the 

footnote disclosures included in the quarterly 

Form 3-Q. 

Order No. 646, P 38 reads 

“Quarterly financial reporting is a 

supplement to the FERC Annual 

Reports, and it presumes the 

users of the quarterly financial 

reports have read the audited 

financial statements from the 

preceding year, including the 

notes to the annual financial 

statements. Therefore, footnote 

disclosure which would 

substantially duplicate the 

disclosures contained in the 

most recent FERC Annual 

Report may be omitted. 

However, disclosure must be 

provided where events 
Docket No. RM08-5-000 - 110 - 

subsequent to the end of the 

most recent year have occurred 

which have a material effect on 

the respondent”. 

27 Duke 

Should have the ability to copy data into the software 

directly from Microsoft Excel, Word, or from other 

sources such as SEC 10K files. 

See discussion in body of this 

Order. 

28 Duke The FERC software is extremely time consuming and 

requires hours of formatting work. 

The Commission is only aware of 

formatting requirements on 

pages 122-123. 

29 Duke Make it easier to copy and paste blocks of data or text 

into software. 

See discussion in body of this 

Order. 

30 Duke Upgrade help tool so help topics can be entered and 

help screens assist preparers. 

Requires significant software 

update - beyond the scope of 

this proceeding. 

31 Duke 

Printing capabilities in the software need to be 

improved. The ability to print individual pages within 

a section should be available to the user. 

Requires significant software 

update - beyond the scope of 

this proceeding. 

32 Duke 

Form 1, pages 310 and 326 (Sales for Resale and 

Purchase Power): FERC should publish guidelines 

on how to count volumes, particularly volumes 

associated with financial transactions. 

We are reviewing the instructions 

to these pages in order to update 

them as appropriate in a future 

update to Form 1. 

33 Duke Need improved clarification on all field definitions 

within the financial forms. 

We are reviewing the instructions 

to these pages in order to update 

them as appropriate in a future 

update to Form 1. 

34 Duke 

Form 1, page 401A (Electric Energy Account): FERC 

should publish additional instructions on which hours 

should be reported. There is confusion on this page 

pertaining to what data should be included with 

respect to physical versus financial transactions. 

 This issue is beyond the scope 

of this proceeding. 

35 Duke 

Form 1, pages 301 and 326 (Electric Operating 

Revenues and Purchased Power): Duke would like 

clarification on how the statistical classification 

column (b) is being used. 

 This issue is beyond the scope 

of this proceeding. 

36 

New 

York 

Commi

ssion 

The instructions for reporting electric operating 

revenues should be clarified to ensure consistency. 

In order to ensure consistency, the instructions on 

pages 300-301 of Form 1 should indicate that 

delivery-only revenues shall be recorded as Other 

Electric Revenues (Account 456), while sales of 

electricity shall be recorded on a full-service basis 

(Accounts 440 through 448), assuming the USofA is 

not revised to provide for an unbundling of electric 

operating revenues. 

The instructions are being 

revised as discussed in the body 

of Order. 

 
Docket No. RM08-5-000 - 111 - 

Appendix C: List of Commenters 

Company Name Abbreviation

 

1. American Electric Power AEP

2. American Public Power Association APPA

3. Bonneville Power Administration BPA

4. Cogentrix Energy, LLC* Cogentrix

5. Duke Energy Corporation Duke

6. Edison Electric Institute EEI

7. FirstEnergy Service Company FirstEnergy

8. International Transmission Company (ITC), Michigan 

Electric Transmission Co., LLC (METC), and ITC 

Midwest LLC** 

International Transmission

9. Michigan Public Service Commission Michigan Commission

10. MidAmerican Energy Co., and PacifiCorp MidAmerican

11. Nevada Power Company and Sierra Pacific Power 

Company 

Nevada Companies

12. New York State Public Service Commission New York Commission

13. Oklahoma Corporation Commission Oklahoma Commission

14. San Diego Gas & Electric Company SDG&E

15. Transmission Access Policy Study Group TAPS

 

* Filed comments out of time. 

** ITC and METC filed reply comments.