[Federal Register Volume 69, Number 188 (Wednesday, September 29, 2004)]
[Proposed Rules]
[Pages 58112-58115]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 04-21760]


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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

18 CFR Parts 35, 41, 101, 141

[Docket No. RM04-12-000]


Financial Reporting and Cost Accounting, Oversight and Recovery 
Practices for Regional Transmission Organizations and Independent 
System Operators

September 16, 2004.
AGENCY: Federal Energy Regulatory Commission.

ACTION: Notice of inquiry.

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SUMMARY: The Federal Energy Regulatory Commission (Commission) is 
inviting comments on its accounting and financial reporting 
requirements for and oversight of regional transmission organization 
(RTO) and independent system operator (ISO) costs.

DATES: Comments on this NOI are due on November 4, 2004.

ADDRESSES: Comments may be filed electronically via the eFiling link on 
the Commission's Web site at http://www.ferc.gov. Commentors unable to 
file comments electronically must send an original and 14 copies of 
their comments to: Federal Energy Regulatory Commission, Office of the 
Secretary, 888 First Street NE., Washington, DC 20426. Refer to the 
Procedure for Comments section of the preamble for additional 
information on how to file comments.

FOR FURTHER INFORMATION CONTACT:
Mark Hegerle (Technical Information), Office of Markets, Tariffs & 
Rates--Central, Federal Energy Regulatory Commission, 888 First Street, 
NE., Washington, DC 20426, (202) 502-8287, <a href="/cdn-cgi/l/email-protection#4904283b2267012c2e2c3b252c092f2c3b2a672e263f"><span class="__cf_email__" data-cfemail="4904283b2267012c2e2c3b252c092f2c3b2a672e263f">[email protected]</span></a>.

Mark Klose (Accounting Information), Office of Executive Director--
Regulatory Accounting Policy Division, Federal Energy Regulatory 
Commission, 888 First Street, NE., Washington, DC 20426, (202) 502-
8283, <a href="/cdn-cgi/l/email-protection#a0edc1d2cb8eebcccfd3c5e0c6c5d2c38ec7cfd6"><span class="__cf_email__" data-cfemail="b2ffd3c0d99cf9deddc1d7f2d4d7c0d19cd5ddc4">[email protected]</span></a>.
Lodie White (Legal Information), Office of General Counsel--Markets, 
Tariffs & Rates, Federal Energy Regulatory Commission, 888 First 
Street, NE., Washington, DC 20426, (202) 502-6193, 
<a href="/cdn-cgi/l/email-protection#115d7e7578743f467978657451777463723f767e67"><span class="__cf_email__" data-cfemail="773b18131e1259201f1e0312371112051459101801">[email protected]</span></a>.

SUPPLEMENTARY INFORMATION: 

Notice of Inquiry

Introduction

    1. The Federal Energy Regulatory Commission (Commission) is issuing 
this Notice of Inquiry to seek comments on its accounting and financial 
reporting requirements for and oversight of regional transmission 
organization (RTO) and independent system operator (ISO) costs. 
Specifically, the Commission is undertaking a review of:

    (a) Whether changes are needed to the Uniform System of Accounts 
Prescribed for Public Utilities and Licensees Subject to the 
Provisions of the Federal Power Act (USofA), (18 CFR part 101), to 
better account and report RTO and ISO financial information to the 
Commission, in order to provide greater transparency of transactions 
and business functions affecting these entities and their member 
transmission-owning public utilities;
    (b) Whether RTOs and ISOs have appropriate incentives to be cost 
efficient; and
    (c) Whether the Commission's rate review methods for RTOs and 
ISOs are sufficient.

Background

    2. In Order No. 888,\1\ the Commission encouraged but did not 
require the formation of ISOs--independent entities that administer 
regional transmission tariffs and control the transmission facilities 
of their member transmission-owning utilities. Rather, Order No. 888 
delineated eleven principles defining the operations and structure of a 
properly functioning ISO. Likewise, in Order No. 2000,\2\ the 
Commission encouraged utilities to voluntarily join RTOs, and detailed 
certain functions an RTO must perform and characteristics that an RTO 
should have.\3\ However, in neither rule did the Commission promulgate 
specific accounting rules or rate review principles for the new 
entities. The Commission instead chose to rely on existing rules and 
policies applicable to traditional public utilities, i.e., principally 
investor-owned utilities (IOUs).
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    \1\ Promoting Wholesale Competition Through Open Access Non-
discriminatory Transmission Services by Public Utilities; Recovery 
of Stranded Costs by Public Utilities and Transmitting Utilities, 
Order No. 888, 61 FR 21,540 (May 10, 1996), FERC Stats. & Regs. ] 
31.036 (1996), order on reh'g, Order No. 888-A, 62 FR 12,274 (March 
14, 1977), FERC Stats. & Regs. ] 31,048 (1997), order on reh'g, 
Order No. 888-B, 81 FERC ] 61,248 (1997), order on reh'g, Order No. 
888-C, 82 FERC ] 61,046 (1998), aff'd in relevant part sub nom. 
Transmission Access Policy Study Group, et al. v. 225 F.3d 667 (D.C. 
Cir. 2000), aff'd sub nom. New York v. FERC, 535 U.S. 1 (2002).
    \2\ Regional Transmission Organizations, Order No. 2000, 65 FR 
809 (January 6, 2000), FERC Stats. & Regs., ] 31,089 (1999), order 
on reh'g, Order No. 2000-A, 65 FR 12,088 (March 8, 2000), FERC 
Stats. & Regs. ] 31,092 (2000), affirmed sub nom. Public Utility 
District No. 1 of Snohomish County, Washington, et al. v. FERC, 272 
F.3d 607 (D.C. Cir. 2001).
    \3\ ISOs and RTOs are, in many respects, similar, with one major 
difference being that RTOs must meet more stringent independence and 
scope and configuration standards.
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    3. Over the past seven years, beginning in 1997, the Commission 
issued a series of orders approving several ISOs and RTOs which have 
since commenced operations. PJM Interconnection, LLC (PJM), ISO New 
England, Inc. (ISO-NE), and Midwest Independent Transmission System 
Operator, Inc. (Midwest ISO) were first approved (or conditionally 
approved) as ISOs and later as RTOs; New York Independent System 
Operator, Inc. (NYISO) and California Independent System Operator, Inc. 
(CAISO) were approved as ISOs. The Commission has also conditionally 
approved Southwest Power Pool, Inc. (SPP), which currently operates a 
regional transmission tariff, as an RTO. The Commission also 
conditionally approved a number of other RTOs and ISOs which have not 
commenced operations.\4\
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    \4\ RTO West (now Grid West), WestConnect, GridFlorida, 
GridSouth, and SeTrans.
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    4. Each of these entities developed independent of one another, 
using somewhat different business models, software, accounting methods, 
and rate designs to accomplish the same ultimate goal of providing 
open-access (non-discriminatory) regional transmission service. In 
addition, some of these entities administer centrally-dispatched, 
competitive energy markets. These differences have made comparisons 
between entities difficult and raised questions concerning the 
Commission's current accounting and financial reporting rules and our 
current rate review practices for RTOs and ISOs.
    5. Nevertheless there are similarities among RTOs and ISOs as well. 
Each RTO/ISO administers a regional transmission tariff and performs 
system monitoring and planning, as well as

[[Page 58113]]

transmission scheduling--functions that formerly were performed by the 
transmission-owning utilities that now take transmission service under 
the RTO's or ISO's tariff. While there may be some needed redundancy 
with respect to certain functions, such as system reliability 
monitoring, because an RTO/ISO, with its regional focus and reach, 
takes over certain functions previously performed by the transmission-
owning public utilities, ratepayers should, over time, expect to see 
economic synergies resulting from the formation of RTOs.\5\
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    \5\ For example, Order No. 2000 noted one entity's observation 
that there may be transmission functions performed by individual 
company control centers, within existing control areas, or within 
existing reliability councils, that may be better and/or more 
efficiently performed by an RTO.
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Differences Between RTOs and Investor-Owned Utilities

    6. There are several significant differences between RTOs/ISOs and 
vertically integrated public utilities. As noted above, each RTO/ISO 
offers transmission service over a wide region of the country, covering 
multiple IOU and other transmission systems. Many also run energy 
markets and congestion management systems through central dispatch of 
the generation located in their footprint. However, unlike IOUs, RTOs 
and ISOs do not own the transmission and generation facilities under 
their control. In fact, they are required to be independent from any 
market participant.\6\
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    \6\ A market participant is defined in relevant part as any 
entity that, either directly or through an affiliate, sells or 
brokers electric energy, or provides ancillary services to the RTO 
or any other entity (e.g., a member transmission-owning utility), 
which has economic or commercial interests that would be 
significantly affected by the RTO's actions or decisions. See 18 CFR 
35.34(b)(2) (2004).
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    7. RTO and ISO costs are largely associated with sophisticated 
system control and communications hardware and software designed to 
oversee the transmission grid, and, for many, to run energy markets, 
congestion management systems, and transmission scheduling systems. In 
contrast, an IOU's costs are dominated by the costs of generation, 
transmission, and distribution facilities.
    8. In addition, because RTOs/ISOs provide transmission service and 
may operate wholesale markets, they do not provide retail electric 
service, and, therefore, fall under the exclusive jurisdiction of the 
Commission. This means that RTOs and ISOs, unlike vertically integrated 
IOUs, are not subject to direct oversight by state commissions.
    9. Moreover, while the Commission has not mandated any particular 
business model for RTOs and ISOs, all current RTOs and ISOs are not-
for-profit entities.\7\ Each RTO and ISO is required to have an 
independent board of directors and to consult with an advisory 
committee made up of all classes of market participants prior to taking 
action. However, the advisory committee has no ability to block an 
action of the RTO/ISO; it can only offer non-binding advice on budget 
and other matters. Moreover, with for-profit entities, shareholders 
face a risk of lower earnings if costs are found to be imprudent and 
ineligible for rate recovery. The not-for-profit status of RTOs/ISOs 
makes cost review more difficult. As the Commission has previously 
observed, with respect to one of these RTOs, ``Midwest ISO's non-profit 
status complicates a prudence review after the costs are incurred.'' 
\8\
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    \7\ One exception is that PJM earns money for its members when 
it sells software and technology to other transmission providers. 
Nevertheless, like the other RTOs, PJM does not have shareholders 
and passes through all of its costs of operation to its market 
participants.
    \8\ Midwest Independent Transmission System Operator, 101 FERC ] 
61,221 at P 35 (2002), order on reh'g, 103 FERC ] 61,035 (2003).
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Current RTO Accounting, Financial Reporting and Cost Recovery Practices

    10. Despite their differences, RTOs/ISOs are public utilities under 
the Federal Power Act and, like traditional public utilities, must 
follow the USofA.\9\ However, the USofA was developed for traditional 
public utilities, i.e., public utilities that provide electric 
generation, transmission, and distribution service. The accounting 
rules contained in the USofA provide for capturing financial 
information along these primary functional business lines.\10\ However, 
meaningful functional business segments or service lines for RTOs and 
ISOs seem quite different. Meaningful business lines for RTOs might 
include ``grid reliability,'' ``ancillary services,'' or ``energy 
markets,'' to suggest a few possibilities. But because RTOs use the 
Commission's existing USofA to capture and classify costs, their 
financial statements and other reports prepared from their accounting 
records may not provide sufficient information about their costs and 
the relationship to services provided or other business activities.
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    \9\ See 18 CFR Part 101.
    \10\ The Commission has explained that RTOs and ISOs are public 
utilities, and as such, they are required to follow the USofA and 
file Form No. 1. See PJM Interconnection, L.L.C. et al., 107 FERC ] 
61,087 (2004).
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    11. Likewise, the current USofA may not provide sufficient 
transparency with respect to changes in RTO- and ISO-member 
transmission-owning public utilities' costs to reflect that the RTO/ISO 
is performing all or a portion of certain functions that were 
previously performed by the transmission-owning utilities.
    12. Differences also exist among RTOs/ISOs with respect to 
operations, rate design, and accepted rate review methodologies. For 
example, RTOs/ISOs, while progressing at differing paces, perform 
similar functions with respect to overseeing the transmission grid and 
running markets. However, rather than building on the work of others, 
each RTO/ISO has developed, or contracted with vendors to develop, 
proprietary software to run its complex systems. The cost of each 
RTO's/ISO's software package, while largely designed to do similar 
tasks, varied considerably.
    13. With respect to rate design differences, as an example, NYISO 
has just one charge to recover all of its costs to administer its 
transmission tariff, energy markets, and congestion management system, 
including its auction of transmission congestion contracts (comparable 
to firm transmission rights (FTRs)).\11\ However, ISO-NE and Midwest 
ISO have three charges, PJM five, and CAISO seven to recover comparable 
costs. Some use formula rates with true-ups; others calculate stated 
rates for the following calendar year. There are also differences among 
the RTOs/ISOs with respect to the billing determinants used to 
calculate similar charges.
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    \11\ NYISO also has separate charges for unbudgeted costs, and 
start-up and formation costs.
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    14. RTOs/ISOs develop their proposed rates through a collaborative 
process with their respective advisory committee processes. In general, 
the RTO/ISO determines the cost side of the equation based on the level 
of expenditures budgeted to accomplish the RTO's/ISO's functions,\12\ 
and works with its stakeholders through the advisory committee process 
to arrive at a proposed allocation methodology, which is filed with the 
Commission (under section 205 of the FPA).\13\ The Commission has 
largely relied on each advisory committee process as a check on RTO 
expenditures and has focused primarily on the review of the cost 
allocation and rate design methodologies. In addition, the Commission 
required one RTO,

[[Page 58114]]

Midwest ISO, to file its annual budget and progress reports on 
expenditures related to market development for informational 
purposes.\14\ The Commission reasoned that the informational filings 
would ``provide a sufficient opportunity to review and compare the 
proposed costs with the actual costs and allow the Commission to 
monitor Midwest ISO's cost containment efforts.'' \15\
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    \12\ The costs incurred by the RTO/ISO are tied to the services 
it performs on behalf of its market participants. The RTO/ISO would 
not, therefore, take an additional functions without an approving 
vote of its advisory committee or a directive by the Commission.
    \13\ 15 U.S.C. 824d (2000).
    \14\ See, e.g., Midwest Independent Transmission System 
Operator, 101 FERC ] 61,221 (2002), order on reh'g, 103 FERC ] 
61,035 (2003)
    \15\ Id., 101 FERC ] 61,221 at P 36.
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    15. Nevertheless, in all cases, RTOs/ISOs are typically allowed 
recovery of all expenditures; they do not absorb losses and instead 
pass through all costs that they incur (e.g., NYISO has a separate 
charge for unbudgeted expenses; Midwest ISO's Schedule 10 charge, while 
capped at $0.15/MWh, allows for the deferral, with interest, of any 
costs which would cause the rate to exceed the cap during one period to 
be recovered during a later period when actual costs for that period 
are less than the capped rate).

The Subject of the Notice of Inquiry

    16. The Commission wants to explore whether changes to RTO/ISO 
accounting, financial reporting, and cost recovery practices are 
necessary to ensure the rates charged by RTOs/ISOs and their member 
transmission-owning public utilities are just and reasonable. Rate 
review mechanisms, including the accounting and financial reporting 
requirements contained in quarterly and annual financial reports 
applicable to traditional public utilities may no longer be 
sufficiently descriptive to reflect RTO/ISO operations due to their 
structure and business functions. Secondarily, current financial 
reporting by RTOs/ISOs and their member transmission-owning public 
utilities owners may not provide the Commission and others sufficient 
transparency of financial trends and emerging issues.
    17. As noted above, the Commission's expectation has been that the 
RTO/ISO would spend only for the benefit of its market participants. 
The RTO/ISO looked to stakeholders for advice on whether to pursue 
particular tariff or market design changes which, of course, would 
necessitate agreement on spending to bring those changes to fruition. 
However, RTO/ISO stakeholders (including member transmission-owning 
utilities) have alleged in various forums that this process provides an 
insufficient check, noting that they only see the budget after it is 
finalized and they have no veto power. In this regard, member 
transmission-owning utilities subject to state commission regulation 
complain that the absence of sufficient oversight of RTO/ISO spending 
results in their being forced to justify before their state commissions 
the prudence of RTO/ISO expenditures.

Questions for Response

    18. The Commission encourages any and all comments regarding the 
topics broadly discussed above. In addition the Commission seeks 
responses to the following specific questions:

A. Accounting and Financial Reporting Issues for RTOs/ISOs

    1. Are the individual account descriptions and instructions 
under the existing USofA adequate for the functions typically 
performed by RTOs/ISOs? If not, what changes should be made to the 
account descriptions and instructions under the existing USofA to 
accommodate the RTO/ISO business model? Are the changes so extensive 
that an entirely separate USofA should be developed to accommodate 
RTOs/ISOs?
    2. Under the existing USofA costs are accounted for as electric 
production, transmission, distribution or general plant. What other 
accounts and functional classifications should be provided for RTO/
ISO transactions and events? For example, are additional revenue, 
expense or detailed fixed asset accounts needed?
    3. Should the Commission develop a new financial reporting 
format for the functions typically performed by RTOs/ISOs? If so 
what financial information and financial-related information should 
be reported? If not, how may the existing annual and quarterly 
financial reports be changed or modified to report relevant RTO/ISO 
transactions and events?
    4. Is additional accounting and financial reporting guidance 
needed for market operation and market monitoring functions of RTOs/
ISOs? If so what transactions and events require additional 
accounting and financial reporting guidance?
    5. Is there sufficient detailed financial and financial-related 
information being provided to users of RTO/ISO data? If not, what 
additional information would the users of the information find 
helpful and why? For example, if detailed information technology 
cost data is necessary, would it also be helpful for the RTO/ISO to 
include the cost driver of the data (e.g., quantity of desktop 
computers in relationship to the number of employees)?
    6. Currently the quarterly and annual Commission financial 
reports include a schedule that requires respondents to report data 
concerning the transmission of electricity for others. Should RTOs/
ISOs report transmission of electric for others for its Commission-
jurisdictional members or should those individual members report the 
information in their individual filings? If the RTO/ISO should 
report the information, what information should be reported and how 
should it be shown in the filing?

B. Accounting and Financial Reporting Issues for Public Utilities and 
Licensees That Are Members of an RTO/ISO

    1. Are the individual account descriptions and instructions 
under the existing USofA useful and applicable for classifying 
revenues received from RTOs/ISOs? If not, what changes should be 
made to the account descriptions and instructions under the existing 
USofA to accommodate these transactions and events?
    2. Are the individual account descriptions and instructions 
under the existing USofA useful and applicable for classifying costs 
related to providing various services such as ancillary services, 
energy markets, or costs associated with transmission congestion? If 
not, what changes should be made to the existing USofA to 
accommodate these transactions and events?
    3. What additional detailed information should be collected or 
disclosed in the quarterly and annual Commission financial reports 
of individual utilities to provide greater transparency of RTO 
transactions and events?
    4. What additional disclosures should be made in the quarterly 
and annual Commission financial reports of individual utilities to 
describe the economic effects resulting from the respondent 
transmitting public utility participating in an RTO?
    5. Does the Commission's USofA and existing financial reporting 
requirements for public utility members of RTO/ISOs provide 
regulators with adequate information to clearly identify which 
functions are performed by the RTO/ISO and which are performed by 
the member transmission-owning public utilities, and to ensure that 
costs are not being double recovered through either Commission-
jurisdictional or state-jurisdictional rates? Are they adequate to 
determine how RTO/ISO costs billed to public utility members should 
enter into the determination of retail rates? If not, what changes 
to the Commission's accounting and reporting rules should be made?

C. Cost Management

    1. Do not-for-profit RTOs/ISOs currently have the appropriate 
incentives to contain costs? If not, what are the right incentives 
(and why would they be the right incentives) and how should they be 
implemented?
    2. Should the Commission revisit the means by which RTO/ISO 
rates are reviewed, particularly with respect to cost incurrence? If 
so, what means should the Commission employ to ensure that RTOs'/
ISOs' expenditures are prudent and their rates are just and 
reasonable? Would a ``best practices'' or ``benchmark'' approach, 
where one RTO/ISO's expenditures in a particular cost category are 
measured against those of other RTOs/ISOs, be sufficient?
    3. What is the appropriate role for the Commission with respect 
to overseeing RTO/ISO software costs? Should an RTO/ISO be required 
to justify contracting for the development of new software rather 
than using or modifying ``off-the-shelf'' software developed for a 
comparable application for or by another RTO/ISO? To what extent 
would

[[Page 58115]]

the use of standardized or at least compatible software in 
neighboring RTO/ISO markets reduce the cost of doing business across 
RTO/ISO boundaries? How would any such standardization be 
accomplished?
    4. To what degree should an RTO/ISO's stakeholder/advisory 
committee be involved in reviewing or shaping the RTO/ISO's budget 
and spending decisions? Are there independence considerations that 
should prevent or limit such review by market participants?
    5. Should the Commission allow differences between RTOs/ISOs 
with regard to cost allocation and rate design to recover the 
operation and capital costs for each of their functions (e.g., 
tariff administration and markets for energy, ancillary service, and 
FTRs)? If so, how should the various rates be designed, i.e., what 
are the correct billing determinants for each service?
    6. Should the compensation of senior RTO/ISO management be 
linked to specific performance measures, including cost reductions?

Procedure for Comments

    19. The Commission invites interested persons to submit comments, 
and other information on the matters, issues and specific questions 
identified in this notice. Comments are due November 4, 2004. Comments 
must refer to Docket No. RM04-12-000, and must include the commentor's 
name, the organization they represent, if applicable, and their 
address.
    20. To facilitate the Commission's review of the comments, 
commentors are requested to provide an executive summary of their 
position. Commentors are requested to identify each specific question 
posed by the NOI that their discussion addresses and to use appropriate 
headings. Additional issues the commentors wish to raise should be 
identified separately. The commentors should double space their 
comments.
    21. Comments may be filed on paper or electronically via the 
eFiling link on the Commission's Web site at http://www.ferc.gov . The 
Commission accepts most standard word processing formats and commentors 
may attach additional files with supporting information in certain 
other file formats. Commentors filing electronically do not need to 
make a paper filing. Commentors that are not able to file comments 
electronically must send an original and 14 copies of their comments 
to: Federal Energy Regulatory Commission, Office of the Secretary, 888 
First Street NE., Washington, DC 20426.
    22. All comments will be placed in the Commission's public files 
and may be viewed, printed, or downloaded remotely as described in the 
Document Availability section below. Commentors are not required to 
serve copies of their comments on other commentors.

Document Availability

    23. In addition to publishing the full text of this document in the 
Federal Register, the Commission provides all interested persons an 
opportunity to view and/or print the contents of this document via the 
Internet through the Commission's Home Page (http://www.ferc.gov ) and 
in the Commission's Public Reference Room during normal business hours 
(8:30 a.m. to 5 p.m. Eastern time) at 888 First Street, NE., Room 2A, 
Washington DC 20426.
    24. 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) in the docket number field.
    25. User assistance is available for eLibrary and the Commission's 
Web site during normal business hours. For assistance, please contact 
the Commission's Online Support at 1-866-208-3676 (toll free) or 202-
502-6652 (e-mail at <a href="/cdn-cgi/l/email-protection#296f6c7b6a66474540474c7a5c5959465b5d694f4c5b4a074e465f"><span class="__cf_email__" data-cfemail="367073647579585a5f585365434646594442765053445518515940">[email protected]</span></a> or the Public Reference 
Room at 202-502-8371, TTY 202-502-8659 (e-mail at 
<a href="/cdn-cgi/l/email-protection#770702151b1e14590512111205121914120518181a371112051459101801"><span class="__cf_email__" data-cfemail="8ffffaede3e6eca1fdeae9eafdeae1eceafde0e0e2cfe9eafdeca1e8e0f9">[email protected]</span></a>)

By direction of the Commission.
Magalie R. Salas,
Secretary.
[FR Doc. 04-21760 Filed 9-28-04; 8:45 am]
BILLING CODE 6717-01-P


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