```

[Federal Register Volume 77, Number 164 (Thursday, August 23, 2012)]
[Notices]
[Pages 50998-51020]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2012-20589]

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COMMODITY FUTURES TRADING COMMISSION

Proposal To Exempt Certain Transactions Involving Not-for-Profit 
Electric Utilities; Request for Comments

AGENCY: Commodity Futures Trading Commission.

ACTION: Notice.

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SUMMARY: The Commodity Futures Trading Commission (``CFTC'' or the 
``Commission'') is proposing to exempt certain transactions between 
not-for-profit utilities (entities described in section 201(f) of the 
Federal Power Act (``FPA'')), and other electric utility cooperatives, 
from the provisions of the Commodity Exchange Act (``CEA'' or ``Act'') 
and the regulations there under, subject to certain antifraud, anti-
manipulation, and recordkeeping conditions. Authority for this 
exemption is found in section 4(c) of the CEA. The Commission is 
requesting comment on every aspect of this Notice of Proposed Order 
(``Notice'').

DATES: Comments must be received on or before September 24, 2012.

ADDRESSES: You may submit comments by any of the following methods:
     Agency Web site, via its Comments Online process: http://comments.cftc.gov. Follow the instructions for submitting comments 
through the Web site.
     Mail: David A. Stawick, Secretary of the Commission, 
Commodity Futures Trading Commission, Three Lafayette Centre, 1155 21st 
Street NW., Washington, DC 20581.
     Courier: Same as mail above.
     Federal eRulemaking Portal: http://www.regulations.gov. 
Follow the instructions for submitting comments.
    Please submit your comments using only one method.
    All comments must be submitted in English, or if not, accompanied 
by an English translation. Comments will be posted as received to 
http://www.cftc.gov. You should submit only information that you wish 
to make available publicly. If you wish the CFTC to consider 
information that you believe is exempt from disclosure under the 
Freedom of Information Act, a petition for confidential treatment of 
the exempt information may be submitted according to the procedures 
established in Sec.  145.9 of the CFTC's regulations.\1\
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    \1\ 17 CFR 145.9.
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    The CFTC reserves the right, but shall have no obligation, to 
review, pre-screen, filter, redact, refuse or remove any or all of your 
submission from http://www.cftc.gov that it may deem to be 
inappropriate for publication, such as obscene language. All 
submissions that have been redacted or removed that contain comments on 
the merits of this action will be retained in the public comment file 
and will be considered as required under the Administrative Procedure 
Act and other applicable laws, and may be accessible under the Freedom 
of Information Act.

FOR FURTHER INFORMATION CONTACT: David Van Wagner, Chief Counsel, (202) 
418-5481, dvanwagner@cftc.gov, or Graham McCall, Attorney Advisor, 
(202) 418-6150, gmccall@cftc.gov, Division of Market Oversight, 
Commodity Futures Trading Commission, Three Lafayette

[[Page 50999]]

Centre, 1155 21st Street NW., Washington, DC 20581.

SUPPLEMENTARY INFORMATION:

Table of Contents

I. Introduction
    A. CEA Section 4(c)
    B. FPA Section 201(f)
II. Petition
    A. Relief Requested
    B. Definition and Scope of Electric Operations-Related 
Transactions
    1. Electric Energy Delivered
    2. Generation Capacity
    3. Transmission Services
    4. Fuel Delivered
    5. Cross-Commodity Transaction
    6. Other Goods and Services Agreements, Contracts and 
Transactions
    7. Environmental Rights, Allowances or Attributes
    C. Definition and Scope of NFP Electric Entities
    1. FPA 201(f) Entities
    a. Government and Cooperatively Owned Electric Utilities 
Described by FPA Section 201(f)
    b. Federally-Recognized Indian Tribes
    2. Non-FPA 201(f) Electric Cooperatives
III. Commission Determinations
    A. Scope of the Proposed Order
    1. Exempt Entities
    a. Electric Utilities Owned by Federal, State, or Local 
Government
    b. Electric Utilities Owned by an Indian Tribe
    c. Electric Utilities Owned as Cooperative Organizations
    2. Exempt Non-Financial Energy Transactions
    3. Conditions
    B. CEA Section 4(c) Considerations
    1. Responsible Economic or Financial Innovation and Fair 
Competition
    2. Applicability of CEA Section 4(a)
    3. Public Interest and Purposes of the CEA
    a. Public Interest
    b. Purposes of the CEA
    4. Appropriate Persons
    5. Ability to Discharge Regulatory or Self-Regulatory Duties
IV. Proposed Order
V. Request for Comment
VI. Related Matters
    A. Regulatory Flexibility Act
    B. Paperwork Reduction Act
    C. Consideration of Costs and Benefits

I. Introduction

    On June 8, 2012, the Commission received a petition (``Petition'') 
\2\ from a group of trade associations that represent government and/or 
cooperatively-owned electric utilities requesting relief from the 
requirements of the CEA \3\ and Commission's regulations thereunder,\4\ 
pursuant to CEA section 4(c),\5\ for certain electric energy-related 
transactions between not-for-profit electric energy utilities. In this 
Notice, after summarizing and reviewing the representations made in the 
Petition, the Commission proposes conditional relief pursuant to CEA 
section 4(c) for non-financial energy transactions between not-for-
profit utilities described in FPA section 201(f) and other electric 
cooperatives.
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    \2\ The Petition is available on the Commission's Web site at 
http://www.cftc.gov/stellent/groups/public/@rulesandproducts/documents/ifdocs/nrecaetalltr060812.pdf.
    \3\ 7 U.S.C. 1 et seq.
    \4\ The Commission's regulations are set forth in title 17 of 
the Code of Federal Regulations (``CFR'').
    \5\ 7 U.S.C. 6(c).
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A. CEA Section 4(c)

    Section 4(c) of the CEA provides the Commission with broad 
authority to exempt certain transactions and market participants from 
the requirements of the Act. When adding section 4(c) to the CEA, 
Congress noted that the goal of the provision ``is to give the 
Commission a means of providing certainty and stability to existing and 
emerging markets so that financial innovation and market development 
can proceed in an effective and competitive manner.'' \6\ The House-
Senate Conference Committee reconciling the provision's language noted 
that:
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    \6\ House Conf. Report No. 102-978, 1992 U.S.C.C.A.N. 3179, 3213 
(``4(c) Conf. Report'').

    The Conferees do not intend that the exercise of exemptive 
authority by the Commission would require any determination 
beforehand that the agreement, instrument, or transaction for which 
an exemption is sought is subject to the [CEA]. Rather, this 
provision provides flexibility for the Commission to provide legal 
certainty to novel instruments where the determination as to 
jurisdiction is not straightforward. Rather than making a finding as 
to whether a product is or is not a futures contract, the Commission 
in appropriate cases may proceed directly to issuing an 
exemption.\7\
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    \7\ 4(c) Conf. Report at 3214-3215.
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    Specifically, CEA section 4(c)(1) empowers the CFTC to ``promote 
responsible economic or financial innovation and fair competition'' by 
exempting any transaction (or class thereof) that otherwise would be 
subject to CEA section 4(a), or any person (or class thereof) dealing 
in such transaction(s), from any or all of the provisions of the CEA 
where the Commission determines that the exemption would be consistent 
with the public interest.\8\ The Commission may grant such an exemption 
by rule, regulation or order, after notice and opportunity for hearing, 
and may do so on application of any person \9\ or on its own 
initiative.
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    \8\ Section 4(c)(1) of the CEA, 7 U.S.C. 6(c)(1), provides in 
full that:
    In order to promote responsible economic or financial innovation 
and fair competition, the Commission by rule, regulation, or order, 
after notice and opportunity for hearing, may (on its own initiative 
or on application of any person, including any board of trade 
designated or registered as a contract market or derivatives 
transaction execution facility for transactions for future delivery 
in any commodity under section 7 of this title) exempt any 
agreement, contract, or transaction (or class thereof) that is 
otherwise subject to subsection (a) of this section (including any 
person or class of persons offering, entering into, rendering advice 
or rendering other services with respect to, the agreement, 
contract, or transaction), either unconditionally or on stated terms 
or conditions or for stated periods and either retroactively or 
prospectively, or both, from any of the requirements of subsection 
(a) of this section, or from any other provision of this chapter * * 
* if the Commission determines that the exemption would be 
consistent with the public interest.
    \9\ CEA section 1a(38) defines ``person'' to include 
``individuals, associations, partnerships, corporations, and 
trusts.'' 7 U.S.C. 1a(38).
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    CEA section 4(c)(2) provides that the Commission shall not grant 
any exemption under section 4(c)(1) from any of the requirements of 
section 4(a) unless the Commission determines, among other things, 
that: (i) the exemption would be consistent with the public interest 
and the purposes of the CEA; (ii) the exempt agreement, contract, or 
transactions will be entered into solely between ``appropriate 
persons;'' and (iii) the exemption will not have a material adverse 
effect on the ability of the Commission or any contract market to 
discharge its regulatory or self-regulatory duties under the CEA.\10\
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    \10\ See 7 U.S.C. 6(c)(2).
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    CEA section 4(c)(3) outlines which entities may constitute 
``appropriate person[s]'' for purposes of a CEA section 4(c) exemption, 
including (as relevant to this Notice): (i) Any governmental entity 
(including the United States, any State, or any foreign government) or 
political subdivision thereof, or any multinational or supranational 
entity or any instrumentality, agency, or department of any of the 
foregoing; \11\ or (ii) such other persons that the Commission 
determines to be appropriate in light of their financial or other 
qualifications, or the applicability of appropriate regulatory 
protections.\12\
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    \11\ See 7 U.S.C. 6(c)(3)(H).
    \12\ See 7 U.S.C. 6(c)(3)(K).
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    The Dodd-Frank Wall Street Reform and Consumer Protection Act 
(``Dodd-Frank Act'') \13\ added new subparagraph

[[Page 51000]]

4(c)(6)(C) to the CEA.\14\ CEA section 4(c)(6)(C) builds upon the 
Commission's general exemptive authority in section 4(c)(1) as follows:
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    \13\ Pub. L. 111-203, 124 Stat. 1376 (2010). The text of the 
Dodd-Frank Act may be accessed at http://www.cftc.gov/LawRegulation/DoddFrankAct/index.htm. Title VII of the Dodd-Frank Act amended the 
CEA to establish a comprehensive new regulatory framework for swaps 
and security-based swaps. The legislation was enacted to reduce 
risk, increase transparency, and promote market integrity within the 
financial system by, among other things: (1) providing for the 
registration and comprehensive regulation of swap dealers (``SDs'') 
and major swap participants (``MSPs''); (2) imposing clearing and 
trade execution requirements on standardized derivative products; 
(3) creating robust recordkeeping and real-time reporting regimes; 
and (4) enhancing the Commission's rulemaking and enforcement 
authorities with respect to, among others, all registered entities 
and intermediaries subject to the Commission's oversight.
    \14\ 7 U.S.C. 6(c)(6)(C) (as added by section 722(f) of the 
Dodd-Frank Act).

    (6) If the Commission determines that the exemption would be 
consistent with the public interest and the purposes of this Act, 
the Commission shall, in accordance with [CEA sections 4(c)(1) and 
4(c)(2)], exempt from the requirements of this Act an agreement, 
contract, or transaction that is entered into--
    [* * *]
    (C) between entities described in section 201(f) of the Federal 
Power Act (16 U.S.C. 824(f)).

    Thus, section 4(c)(6)(C) explicitly spotlights transactions between 
entities within the scope of FPA section 201(f) as being eligible for 
exemption pursuant to the Commission's 4(c) authority. However, whether 
an exemption is considered under 4(c)(1), 4(c)(6)(C), or both,\15\ the 
CFTC must first determine that the proposed exemption meets certain 
threshold criteria including, for example, that the exemption would be 
consistent with the public interest and the purposes of the Act.
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    \15\ For any exemption involving CEA section 4(c)(6), the 
Commission believes ``both'' is the correct characterization because 
CEA section 4(c)(6) explicitly directs the Commission to consider 
any exemption proposed under 4(c)(6) ``in accordance with [sections 
4(c)(1) and 4(c)(2)].''
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B. FPA Section 201(f)

    The FPA \16\ authorizes and, along with other statutes, governs the 
Federal Energy Regulatory Commission (``FERC''), the federal agency 
that regulates the interstate transmission and sale at wholesale in 
interstate commerce of electric energy by public utilities, as well as 
natural gas and hydropower projects.\17\ Section 201(f) of the FPA, 
which Congress referenced in new CEA section 4(c)(6)(C), provides 
broad-based relief from most provisions of Part II \18\ of the FPA for 
certain government and cooperatively-owned electric utility companies 
and states that:
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    \16\ 16 U.S.C. 791a et seq.
    \17\ See www.ferc.gov.
    \18\ Part II of the FPA governs the transmission and sale at 
wholesale of electric energy in interstate commerce, including the 
facilities used for such transmission or sale. See 16 U.S.C. 824 et 
seq. Section 201(f) does not, however, provide an exemption from FPA 
parts I or III. Part I of the FPA deals with the establishment and 
functioning of FERC and the regulation of hydroelectric resources. 
See 16 U.S.C. 792 et seq. Part III of the FPA deals with 
recordkeeping and reporting requirements and FERC's procedural rules 
concerning complaints, investigations, and hearings. See 16 U.S.C. 
825 et seq. Additionally, section 201(f) does not provide an 
exemption from FERC's refund authority, 16 U.S.C. 824e, reliability 
standards, 16 U.S.C. 824o(b)(1), or jurisdiction over transmission 
facilities and services, 16 U.S.C. 824(i)-(j).

[n]o provision in this subchapter [Part II of the FPA] shall apply 
to, or be deemed to include, the United States, a State or any 
political subdivision of a State, an electric cooperative that 
receives financing under the Rural Electrification Act of 1936 (7 
U.S.C. 901 et seq.) or that sells less than 4,000,000 megawatt hours 
of electricity per year, or any agency, authority, or 
instrumentality of any one or more of the foregoing, or any 
corporation which is wholly owned, directly or indirectly, by any 
one or more of the foregoing, or any officer, agent, or employee of 
any of the foregoing acting as such in the course of his official 
duty, unless such provision makes specific reference thereto.\19\
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    \19\ 16 U.S.C. 824(f).
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II. Petition

A. Relief Requested

    As noted above, on June 8, 2012, the Commission received the 
Petition \20\ from a group of trade associations representing 
government and/or cooperatively-owned electric utilities. Those 
Petitioners consisted of the National Rural Electric Cooperative 
Association (``NRECA''),\21\ the American Public Power Association 
(``APPA''),\22\ the Large Public Power Council (``LPPC''),\23\ the 
Transmission Access Policy Study Group (``TAPS''),\24\ and the 
Bonneville Power Administration (``BPA'') \25\ (collectively, the 
``Petitioners''). The Petition requests that the Commission provide 
categorical exemptive relief from the requirements of the CEA, pursuant 
to CEA section 4(c)(6), in accordance with CEA sections 4(c)(1) and 
4(c)(2), for all ``Electric Operations-Related Transactions'' between 
``NFP Electric Entities,'' retroactive to the enactment of Dodd-Frank, 
outstanding now, or that may be developed and executed in the 
future.\26\ The Petitioner's definition and scope of the terms 
``Electric Operations-Related Transactions'' and ``NFP Electric 
Entities'' is summarized below.\27\
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    \20\ The Petition is available on the Commission's Web site at 
http://www.cftc.gov/stellent/groups/public/@rulesandproducts/documents/ifdocs/nrecaetalltr060812.pdf.
    \21\ According to the Petition, NRECA is the national service 
organization for more than 900 not-for-profit rural electric 
cooperatives and government-owned power districts. NRECA's members 
provide electric energy to approximately 42 million consumers in 47 
states, or thirteen percent of the nation's population. See Petition 
at 3.
    \22\ According to the Petition, APPA is the national trade 
association that represents the interests of government-owned 
electric utilities in the United States. APPA's member utilities are 
not-for-profit utility systems that were created by state or local 
governments to serve the public interest. Approximately 2,000 
government-owned electric utilities provide over fifteen percent of 
all kilowatt hour (``KWh'') sales to retail electric customers. See 
Petition at 3-4.
    \23\ According to the Petition, LPPC is an organization 
representing 24 of the largest government-owned electric utilities 
in the nation. LPPC members own and operate over 86,000 megawatts of 
generation capacity and nearly 35,000 circuit miles of high voltage 
transmission lines, representing nearly 90 percent of the 
transmission investment owned by non-Federal government-owned 
electric utilities in the United States. See Petition at 4.
    \24\ According to the Petition, TAPS is an association of 
transmission dependent electric utilities located in more than 30 
states. All of TAPS member electric utilities except one are FPA 
section 201(f) entities. See Petition at 4.
    \25\ According to the Petition, BPA is a self-financed, non-
profit Federal agency created in 1937 by Congress that primarily 
markets electric power from 31 federally owned and operated 
projects, and supplies 35 percent of the electricity used in the 
Pacific Northwest. BPA also owns and operates 75 percent of the 
high-voltage transmission in the Pacific Northwest. BPA's primary 
statutory responsibility is to market its Federal system power at 
cost-based rates to its ``preference customers.'' Per the Petition, 
BPA has 130 preference customers made up of electric utilities which 
are not subject to the jurisdiction of FERC, including Indian 
tribes, electric cooperatives, and state and municipally chartered 
electric utilities, and other Federal agencies located in the 
Pacific Northwest. See Petition at 4.
    \26\ See Petition at 1-2; 4 (emphasis added). The Petition also 
requests that the Commission determine that no Electric Operations-
Related Transaction will affect any NFP Electric Entity's regulatory 
status under the CEA (e.g., as a swap dealer or major swap 
participant). Id. at 28. The Petition specifically asks that, if the 
Commission declines to provide the categorical relief as requested, 
the Commission would i) include an additional category of approved 
Electric Operations-Related Transactions that includes all ``trade 
options'' referencing the goods or services described in the 
categories of transactions currently outstanding between Exempt 
Entities (see infra sections II.B.1-7), and ii) delegate to 
Commission staff the authority to review on an expedited basis and 
approve as eligible for the benefit of the exemptive order any new 
Electric Operations-Related Transactions between NFP Electric 
Entities. Id. at 13. Finally, the Petition invites the Commission to 
determine that any Electric Operations-Related Transaction described 
in the Petition does not need an exemption because such transaction 
is not a ``swap,'' is a ``commercial merchandising arrangement'' or 
``trade option,'' or is not an agreement, contract or transaction 
involving a ``commodity.'' See id. at 13, note 26.
    \27\ In this Notice, the Commission describes the Petition by 
referencing Petitioners' defined terms. Such references, however, 
are not to be interpreted as the Commission proposing to adopt such 
terms for the purpose of the exemption proposed herein. Rather, the 
proposed exemption establishes its own defined entities and 
transactions for which relief is being provided.
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B. Definition and Scope of Electric Operations-Related Transactions

    The Petition defines Electric Operations-Related Transactions to 
mean:

    Any agreement, contract or transaction involving a ``commodity'' 
(as such term is defined in the CEA) and whether or not such 
agreement, contract or transaction is a

[[Page 51001]]

``swap,'' so long as the NFP Electric Entity is entering into any 
such agreement, contract or transaction ``to hedge or mitigate 
commercial risks'' (as such phrase is used in CEA Section 
2(h)(7)(A)(ii)) intrinsically related to the electric facilities or 
electric operations (or anticipated facilities or operations) of the 
NFP Electric Entity, or intrinsically related to the NFP Electric 
Entity's public service obligation to deliver reliable, affordable 
electric energy service to electric customers. For the avoidance of 
doubt, ``intrinsically related'' shall include all transactions 
related to (i) the generation, purchase or sale, and transmission of 
electric energy by the NFP Electric Entity, or the delivery of 
reliable, affordable electric energy service to the NFP Electric 
Entity's electric customers, (ii) all fuel supply for the NFP 
Electric Entity's electric facilities or operations, (iii) 
compliance with electric system reliability obligations applicable 
to the NFP Electric Entity, its electric facilities or operations, 
(iv) compliance with energy, conservation or renewable energy or 
environmental statutes, regulations or government orders applicable 
to the NFP Electric Entity, its electric facilities or operations, 
or (v) any other electric operations-related agreement, contract or 
transaction to which the NFP Electric Entity is a party. Electric 
Operations-Related Transactions shall not include agreements, 
contracts or transactions executed, traded, or cleared on a 
registered entity, nor shall such defined term include an agreement, 
contract or transaction based or derived on, or referencing, a 
``commodity'' in the interest rate, credit, equity or currency asset 
class, or of a product type or category in the ``Other Commodity'' 
asset class that is based or derived on, or referencing, metals, or 
agricultural commodities or crude oil or gasoline commodities of any 
grade not used as fuel for electric generation.\28\
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    \28\ Petition at 4-5.

In general, the Petitioners represent that all Electric Operations-
Related Transactions covered by the proposed definition are 
intrinsically related to the needs of both NFP Electric Entities 
engaged in a transaction ``to hedge or mitigate commercial risks'' 
which arise from their respective electric facilities and ongoing 
electric operations and public service obligations.\29\ The Petitioners 
state that, at the time two NFP Electric Entities enter into an 
Electric Operations-Related Transaction, the terms of the transaction 
contemplate performance of an electric operations-related obligation by 
one party, in exchange for payment or reciprocal performance of an 
electric operations-related function by the other party.\30\
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    \29\ See Petition at 12.
    \30\ See id. The Petition notes that the terms ``physically-
settled,'' ``financially-settled,'' and ``cash-settled,'' as such 
terms are used in the futures industry, do not translate easily into 
a commercial context where NFP Electric Entities enter into 
bilateral contracts governed by state law or by FERC, PUCT or state 
public utility tariffs to buy and sell goods and services. It is not 
readily apparent to the Commission why the terms do not translate 
conceptually. Nevertheless, as previously noted, the Petition 
represents that Electric Operations-Related Transactions between NFP 
Electric Entities are always intrinsically related to the electric 
facilities and operations, and/or the public service obligations, of 
each of the NFP Electric Entities involved. See id. at 12, n. 24.
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    The Petition, which is summarized herein, specifically describes 
seven categories of transactions that currently occur between NFP 
Electric Entities, and which are covered by the Petition's proposed 
definition.\31\
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    \31\ The following transaction category descriptions come from 
the Petition at 6-12.
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1. Electric Energy Delivered
    In these transactions, NFP Electric Entities agree for one such 
entity to provide another such entity with electric energy delivered to 
an identified geographic service territory, load,\32\ or electric 
system. Petitioners note that since electric energy is not currently 
storable in commercial quantities, the delivery location is critical to 
the transaction--electric energy delivered elsewhere is not usable or 
valuable for the receiving entity's operational needs.
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    \32\ The Commission understands that ``load'' is an energy 
industry term for ``demand.'' See, e.g., Current Energy, Supply of 
and Demand for Electricity in California, available at http://currentenergy.lbl.gov/ca/index.php 
(explaining that ``[t]he current demand (or `load') depends on how 
much power consumers are using right now'').
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    As described by the Petitioners, this transaction type includes the 
most prevalent type of Exempt Electric Operations-Related Transaction 
between NFP Electric Entities, i.e., the ``full requirements'' 
contract, or ``all requirements'' agreement or arrangement \33\ that is 
often executed between a generation and transmission (``G&T'') 
cooperative (i.e., a cooperative that generates and transmits 
electricity) and each of its constituent NFP Electric Entity members/
owners, or between a Joint Action Agency (an agency formed under state 
law to provide wholesale power supply and transmission service to 
member entities) and each of its constituent NFP Electric Entity 
members. In some instances, the G&T cooperative or the Joint Action 
Agency is formed by its constituent members for the singular purpose of 
providing its constituent members with their ``full requirements'' 
obligations to deliver electric energy over an agreed delivery period 
at one or multiple delivery points or locations to their retail 
electric customers).
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    \33\ Per the Petition, the ``full'' or ``all'' requirements 
contract is a bilateral commercial arrangement that is customized to 
the two NFP Electric Entities that are parties thereto.
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    In such an arrangement, the provider NFP Electric Entity agrees by 
bilateral contract or, in some long-standing relationships established 
by governing or legal documents of the G&T cooperative or Joint Action 
Agency as the provider NFP Electric Entity, that it will provide for a 
recipient NFP Electric Entity's ``full requirements'' to provide 
reliable electric service to the recipient's fluctuating electric 
energy load over an agreed delivery period at one or multiple delivery 
points or locations. In some cases, the delivery period, term, or 
``tenor'' of such agreements can be for thirty years or more.
    In addition to providing the recipient's full requirements for 
electric energy, the arrangement may also include providing services 
that are ancillary to the delivery of the electric energy, such as 
operating or dispatching one or more of the recipient's owned 
generation units, generation capacity or balancing services, or any of 
the other goods, services, or commodities required by the recipient 
described under other categories below.
    The Petition notes that quantities of electric energy will also 
vary during the delivery period. If a recipient NFP Electric Entity 
owns some generation itself, the quantity of supplemental electric 
energy or capacity to meet its ``full requirements'' during some 
seasons, months, or days of the year (net of its owned generation) may 
be zero. Some ancillary services or ``commodities'' under such a 
transaction may be optional. Pricing may vary on a seasonal, monthly, 
daily or on-peak/off-peak basis, or may be tied to the cost at which 
the provider NFP Electric Entity can generate or purchase electric 
energy. Alternatively, the price may be tied to the fuel that the 
provider uses for generating the electric energy provided.
2. Generation Capacity
    In describing this transaction category, the Petition initially 
notes that the term ``capacity,'' in connection with generation 
capacity transactions, has varying meanings across the electric 
industry, and that electric operations professionals may reference any 
of a number of ``capacity'' agreements, contracts, transactions, or 
arrangements.\34\ More generally, the

[[Page 51002]]

Petition notes that when two NFP Electric Entities agree that one will 
provide ``generation capacity'' or ``capacity'' for another, either a 
mutual understanding of the engineering context or a customized 
bilateral commercial contract further defines the parties' respective 
rights and obligations. Generation capacity is always location-specific 
and is monitored by the regional transmission organization (``RTO'') or 
independent system operator (``ISO'') \35\ or, outside the RTO/ISO 
regions, by balancing authorities or reliability coordinators under the 
supervision of the North American Electric Reliability Corporation 
(``NERC'') and FERC.\36\ Deliverability of generation capacity to a 
particular geographic point or electric system interface is such an 
important concept that FERC requires each RTO, ISO, and balancing 
authority to establish a framework of engineering studies to 
demonstrate/confirm that a particular generation unit's electrical 
energy output is deliverable. If generation capacity from a particular 
unit does not satisfy the relevant RTO, ISO or balancing authority's 
deliverability requirements, that generation capacity has no value in 
meeting reliability requirements in that reliability area. If 
generation capacity is purchased from a generation unit located outside 
the relevant reliability area, the correlated electric energy (which, 
if ``called on,'' must be delivered) nonetheless must be deliverable to 
the relevant reliability area.
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    \34\ Counsel for Petitioners represented in subsequent 
conversations that generation capacity, generally, can mean the 
capability or adequacy of specific owned generation units to supply 
fluctuating load requirements within a defined geographic region 
(e.g., an RTO region or an electric utility system) at an estimated 
or capacity rating level measured in megawatts. The basic concept of 
generation capacity can be understood as a separate ``commodity'' 
from electric energy delivered (or other ancillary service or 
reserve), such that the purchase and sale of generation capacity may 
exist as a stand-alone transaction or as one component of a 
``bundled energy'' service or transaction, such as a full 
requirements contract. When viewed as an ``option-like'' commodity 
transaction, generation capacity can be ``delivered'' if the 
``holder'' (or relevant reliability authority) calls on the 
corollary electric energy to be delivered. In some circumstances, 
the ``premium'' component can be priced separately and referred to 
as a ``demand charge.'' In others, the generation capacity component 
can be a contingent or option-like aspect of a seller's obligation 
to provide the ``full requirements'' that a load serving entity 
(``LSE'') needs to serve the electric consumers and businesses in 
its regions, including fulfillment of any generation capacity 
obligations that the LSE has to its local reliability authority.
    \35\ More information is available at http://www.ferc.gov/industries/electric/indus-act/rto.asp. The current ISO/RTO entities 
operating in North America are PJM Interconnection, Midwest 
Independent Transmission System Operator, Southwest Power Pool, ISO 
New England, California ISO, New York Independent System Operator 
and the Electric Reliability Council of Texas (ERCOT). Each of these 
entities, other than ERCOT, was either formed at the direction of 
FERC or designated by FERC to direct the operation of the regional 
electric transmission grid in its specific geographic area. ERCOT is 
fully regulated by the Public Utility Commission of Texas (the 
``PUCT'').
    \36\ Counsel for Petitioners in subsequent conversations 
represented that generation capacity can be a reliability 
requirement that, in some areas, owners of generation units must 
maintain in order to provide voltage and frequency support to the 
electric grid for reliability purposes. In other areas, generation 
capacity reliability requirements may be imposed on LSEs that must, 
if they own no generation assets, purchase generating capacity from 
third-party generators to fulfill the LSEs' reliability 
requirements.
---------------------------------------------------------------------------

    Some generation capacity agreements or arrangements among NFP 
Electric Entities may include operational reserves attributable to the 
identified generation unit. A generation capacity arrangement or 
transaction also may be called a ``shared resources agreement,'' 
whereby NFP Electric Entities agree conditionally to share capacity 
resources as needed. The contract may relate to multiple identified 
units owned or operated by both NFP Electric Entities. For example, 
some state or regional programs to manage limited generation capacity 
and maintain voltage support for the electric grid in a geographic area 
may allow NFP Electric Entities subject to such program to utilize 
``demand-side resources'' as part of the generation capacity required 
by the specific balancing authority, or to meet the reliability 
authority's requirements in the relevant geographic region.
    In general, a generation capacity transaction between two NFP 
Electric Entities in one region cannot be presumed to be fungible with 
any other generation capacity transaction between two other NFP 
Electric Entities, even in the same region.
3. Transmission Services
    As with the other transaction categories described by the 
Petitioners, the Petition notes that electric transmission services 
transactions between NFP Electric Entities will vary by geographic 
region and by assets owned and transmission services required by the 
operations of different NFP Electric Entities. In some cases, these 
transmission services agreements include congestion management 
services, system losses, and ancillary services.\37\ Some NFP Electric 
Entities own significant transmission facilities (e.g., BPA owns 75 
percent of the transmission lines in the Pacific Northwest). In some 
cases, Federal law and the regulations pursuant to which the Federal 
power agencies are formed and operate require a particular Federal 
power agency to allocate a portion of the transmission to particular 
electric entities, including NFP Electric Entities, located within its 
geographic area.
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    \37\ The Petition notes that the concept of generation capacity 
is distinguishable from ``transmission capacity,'' which relates to 
the limited amount of electric energy transmission available over 
the interconnected electric transmission grid, and which is 
generally defined as a measure of the transfer capability or 
``capacity'' remaining in the physical electric energy transmission 
network for further commercial activity over and above already 
committed uses. Additionally, Exhibit 2 of the Petition provides the 
following example:
    Federal power agency K sells to G&T cooperative J 100 MWs of 
monthly ``firm point-to-point transmission service'' from location X 
to location Y in the southeast U.S. for a term of 3 months at the 
tariff rate of $2,000/MW-Month for a total transaction value of 
$600,000. The geographic area in which such transmission service 
takes place is outside the ``footprint'' of an RTO, and therefore 
the transmission service is reserved on the Open Access Same Time 
Information System (``OASIS'') Web site of the transmission owner, 
K. J intends to use the transmission service to deliver wholesale 
electric power to its distribution cooperative member-owners to 
supply a portion of its distribution cooperative constituents' 
retail electric load.
    Petition Exhibit 2 at 3.
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    In certain areas of the country, the RTOs/ISOs control allocation 
of transmission assets, rights and services, and the individual owners 
of transmission assets do not have the ability to engage in bilateral 
services arrangements involving those transmission assets, which are 
under RTO/ISO management and control. In other areas of the country, 
historical transmission services agreements, including those between 
NFP Electric Entities, are ``grandfathered'' from the RTO/ISO rules and 
procedures otherwise applicable to electric transmission services in 
that region.
4. Fuel Delivered
    The Petition describes a fourth category of transactions in which 
one NFP Electric Entity delivers to another NFP Electric Entity fuel to 
power electric generation facilities. The electric facilities owned and 
operated by NFP Electric Entities vary widely in terms of the fuel used 
by such facilities for generation. Fuel types may include nonfinancial 
commodities such as coal, natural gas, uranium products, heating oil, 
and biomass or waste products including wood chips, tires, and manure. 
In addition to the fuel, one NFP Electric Entity may provide to another 
NFP Electric Entity other services related to the fuel commodity, such 
as fuel procurement, fuel transportation over pipeline, rail, barge and 
truck, fuel storage, or fuel waste handling and storage services.\38\
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    \38\ Petitioners also described a scenario in which one NFP 
Electric Entity may agree to manage for another NFP Electric Entity 
the operational basis or exchange (location/time of delivery) risk 
that arises from the recipient's NFP Electric Entity's location-
specific, seasonal, or otherwise variable operational need for fuel 
delivered. Another example from Exhibit 2 of the Petition provides 
that:
    Joint power agency L supplies to municipal utility M a long-term 
supply of natural gas from a natural gas project (Project Entity Z) 
developed by L and other NFP Electric Entities for the purpose of 
fueling L's and M's (and other NFP Electric Entity owners of Project 
Entity Z's) natural gas-fired electric generating facilities in the 
California ISO market. M pays L for the cost of acquiring, 
developing and improving the natural gas Project Entity Z through 
direct ``capital contributions'' to Project Entity Z. In addition M 
pays L a monthly fee for the natural gas supplied from the natural 
gas project, composed of an operating cost fee component, an 
interstate pipeline transportation cost fee component and an 
operating reserve cost fee component. The natural gas-fired electric 
generating facility is to be used by M to supply a portion of its 
expected retail electric load.
    Petition Exhibit 2 at 3-4.

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[[Page 51003]]

5. Cross-Commodity Transactions
    The Petition describes such transactions as commercial agreements 
entered into between two NFP Electric Entities, including options, heat 
rate transactions and tolling arrangements, whereby the electric energy 
delivered to the recipient NFP Electric Entity is priced by reference 
to the fuel source used or useable by the provider NFP Electric Entity 
for generating such electric energy. Alternatively, the price paid for 
the fuel by the recipient NFP Electric Entity may be calculated by 
reference to the amount of electricity that the recipient NFP Electric 
Entity generates using such fuel.
6. Other Goods and Services
    The Petition notes that these agreements may involve sharing 
property rights, equipment, supplies and services, including 
construction, operation, and maintenance agreements, facilities 
management, construction management, energy management or other energy-
related services tied to the electric facilities owned by, or 
operations of, one or both of the NFP Electric Entities, including 
emergency assistance or ``mutual aid'' arrangements.
    In some regions of the country, state regulators or RTOs/ISOs have 
established ``demand side management programs'' to assist utilities in 
managing the supply/demand balance that is essential to delivering 
reliable electric energy (which is not currently storable in commercial 
quantities). Therefore, some NFP Electric Entities engage in joint 
demand-side management programs with their retail electric customers 
whereby the customers agree to reduce service/load requirements during 
certain weather or emergency conditions. NFP Electric Entities may 
agree with each other to engage in joint demand-side management 
programs to conserve their collective generation resources and reduce 
costs, and to comply with their collective obligations to RTOs/ISOs, 
regional balancing authorities, and state or local regulators.
    The Petition also notes that NFP Electric Entities may provide each 
other with services related to the generation, transmission, and/or 
distribution facilities owned by each, or with respect to the 
maintenance (ongoing, outage, or emergency) or dispatch of generation 
units. Especially when there is a weather event or other unexpected 
outage which interrupts electric energy service to an NFP Electric 
Entity's customers, other NFP Electric Entities (and other electric 
utilities) in the geographic area will provide goods and services on an 
immediate basis, often without the opportunity of negotiating pricing 
or payment terms until the electric energy service has been restored to 
retail electric energy customers. These agreements between NFP Electric 
Entities may involve operating each other's facilities, sharing 
equipment, supplies and employees (e.g., line crews), and interfacing 
on each other's behalf with suppliers/vendors, regulators and 
reliability authorities and customers.
7. Environmental Rights, Allowances or Attributes
    The last category of transactions described in the Petition relates 
to a wide variety of Federal, regional, state, and local environmental 
rights, allowances or attributes required to operate a particular NFP 
Electric Entity's electric facilities or operations, or to fulfill a 
particular NFP Electric Entity's regulatory requirements. NFP Electric 
Entities may transact among themselves in environmental emissions 
allowances, offsets or credits (including carbon), renewable energy, 
distributed generation, clean energy or energy efficiency credits or 
attributes (which can be regional or state specific in nature, 
including ``green tags''). NFP Electric Entities in a particular 
geographic region, whose available allowances may be directly useable 
to fulfill the needs of another NFP Electric Entity in the same region, 
often will directly transact with each other, rather than go to a non-
NFP Electric Entity to negotiate a particular transaction.

C. Definition and Scope of NFP Electric Entities

    The Petition defines NFP Electric Entities as:

    (i) The United States, a State or any political subdivision of a 
State, or (ii) an ``electric cooperative'' that receives financing 
under the Rural Electrification Act of 1936 (7 U.S.C. 901 et seq.) 
or that sells less than 4,000,000 megawatt hours of electricity per 
year, or [(iii) any other electric cooperative, whether or not such 
electric cooperative meets the requirements of clause (ii) 
above,]\1\ or (iv) any agency, authority, instrumentality or 
department of any one or more of the foregoing, or a federally-
recognized Indian tribe, or (v) any entity which is wholly owned, 
directly or indirectly, by any one or more of the foregoing. For 
purposes of this definition, an ``electric cooperative'' shall mean 
an ``electric membership corporation'' or an ``electric power 
association'' organized under State law, a ``rural electric 
cooperative,'' ``cooperative providing electric services to 
consumers and farmers'' or any similar entity referenced in other 
Federal, State and local laws and regulations, so long as any such 
entity is formed and continues to operate for the primary purpose of 
providing electric service to its members on a not-for-profit, 
cooperative basis, and is treated as a cooperative under the Federal 
tax law.\39\

    \39\ Petition at 14 (internal citations omitted).

Generally, the Petition represents that all NFP Electric Entities are 
``nonfinancial end users of Electric Operations-Related Transactions, 
and enter into such transactions only to hedge or mitigate commercial 
risks.'' \40\ Summarized herein, the Petition describes in detail the 
specific classes of entities it believes fall within its proposed NFP 
Electric Entity definition, and justifies inclusion of each specific 
class based upon a common public interest rationale.
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    \40\ Petition at 33. Petitioners explain that the term 
``nonfinancial end users'' means an NFP Electric Entity that does 
not fall within the definition of a ``financial entity'' in CEA 
2(h)(7)(C)(i) and that no NFP Electric Entity falls within that 
definition. See id. at 33-34.
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1. FPA 201(f) Entities
    ``FPA 201(f) entities'' is the first class of NFP Electric Entities 
defined by Petitioners. These entities include i) certain government 
and cooperatively-owned electric utilities (as described in FPA section 
201(f)) and ii) federally-recognized Indian tribes that own or operate 
electric facilities (as determined by FERC case law).
a. Government and Cooperatively-Owned Electric Utilities Described by 
FPA Section 201(f)
    Petitioners seek relief from the CEA and Commission regulations 
there under for those entities explicitly described by FPA section 
201(f) \41\ as being exempt from the plenary jurisdiction of FERC. Per 
the Petition, the first category of these entities includes certain 
government-owned electric utilities, including Federal electric 
utilities such as BPA and other Federal agencies that operate electric 
generating or transmission facilities,\42\

[[Page 51004]]

and state-chartered electric utilities such as the New York Power 
Authority. Other examples of government-owned electric utilities 
include state or county utility boards or public utility districts 
formed under state or local law, joint action agencies or joint power 
agencies formed under state law to provide wholesale power supply and 
transmission services to member entities (each a Joint Action Agency), 
and other political subdivisions of a state.\43\ Finally, municipal 
utilities ranging in size from LPPC members such as the Los Angeles 
Department of Water and Power and the Sacramento Municipal Utility 
District, to the smallest municipal electric utilities with fewer than 
500 electric meters, are also contemplated as government electric 
utilities under FPA section 201(f).\44\
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    \41\ See supra note 19 and accompanying text.
    \42\ Per the Petition, there are nine Federal electric utilities 
in the United States, which are part of several agencies of the 
United States Government:
     The Army Corps of Engineers;
     The Bureau of Indian Affairs and the Bureau of 
Reclamation in the Department of the Interior,
     The International Boundary and Water Commission in the 
Department of State,
     The Power Marketing Administrations in the Department 
of Energy (BPA, Western Area Power Administration, Southwestern Area 
Power Administration, and Southeastern Area Power Administration), 
and
     The Tennessee Valley Authority (TVA).
    In addition, three Federal agencies operate electric generating 
facilities:
     TVA, the largest Federal power producer;
     The U.S. Army Corps of Engineers; and
     The U.S. Bureau of Reclamation.
    \43\ Per the Petition, a public power district or public utility 
district may be owned and operated by a city, county, state or 
regional agency. See, e.g., Public Utility District No. 1 of Chelan 
County, Washington (http://www.chelanpud.org/your-PUD.html). An 
irrigation district is a utility organized under state law which 
generates electricity in the course of supplying water. For example, 
Imperial Irrigation District in California was formed in 1911 under 
the California Irrigation District Act, as described at http://www.iid.com/index.aspx?page=39. Government-owned utilities are 
accountable to elected and/or appointed officials and focus on 
providing reliable and safe electricity service, keeping costs low 
and predictable for its customers, while practicing good 
environmental stewardship.
    \44\ Per the Petition, a government owned or operated electric 
utility may be a department of the governmental entity, or may be 
organized as a separate agency, authority or instrumentality 
thereof.
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    Per the Petition, the second category of entities described by FPA 
section 201(f) are electric cooperatives that either are financed by 
the U.S. Department of Agriculture's Rural Utilities Service (``RUS''), 
sell less than 4,000,000 megawatt hours of electricity per year, or 
meet the requirements of an ``aggregated FPA 201(f) entity.'' These 
electric cooperatives generally consist of (i) distribution 
cooperatives, which distribute electric energy service directly to 
their owner/member customers, and (ii) G&T cooperatives, which are 
owned by distribution cooperatives and generate or purchase electricity 
and transmit it to their constituent distribution cooperatives for 
delivery to the distribution cooperatives' owner/member customers. 
Aggregated entities most commonly consist of a G&T cooperative formed 
by its constituent distribution cooperative (NFP Electric Entity) 
members or, comparably, a Joint Action Agency which is formed by its 
constituent government-owned (NFP Electric Entity) utility members.
    As background, Petitioners explain that the FPA originally was 
enacted ``to remedy rampant abuses in the investor-owned electric 
utility industry'' \45\ but that cooperatively-owned electric utilities 
are easily distinguishable from investor-owned electric utilities 
because they are ``effectively self-regulating.'' \46\ More 
importantly, of the major abuses considered by Congress as the impetus 
for the FPA legislation, ``virtually none could be associated with the 
[electric] cooperative structure where ownership and control is vested 
in the consumer-owners.''\47\ Based on this understanding of the 
legislative history, FERC's predecessor, the Federal Power Commission 
(``FPC''), concluded that electric cooperatives financed under the 
Rural Electrification Act of 1936 (``REA'') \48\ were intended by 
Congress to be FPA 201(f) entities and exempt from the FPC's 
jurisdiction over ``public utilities.'' \49\ The FPC made such a 
determination in the 1960s notwithstanding the fact that, at that time, 
electric cooperatives were not expressly described in FPA section 
201(f).\50\
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    \45\ Salt River Project Agric. Improvement and Power District v. 
 Fed. Power Comm'n, 391 F. 2d 470, 475 (D.C. Cir. 1968) (emphasis 
added by Petitioners).
    \46\ Id. at 473 (elaborating that electric cooperatives are 
``completely owned and controlled by their consumer-members and only 
consumers can become members. They are non-profit. Each member has a 
single vote in the affairs of the cooperative, and services are 
essentially limited to members. No officer receives a salary for his 
services[,] and officers and directors are prohibited from engaging 
in any transactions with the cooperative from which they can earn 
any profit.'') (citation omitted).
    \47\ Id. at 475.
    \48\ 7 U.S.C. 901 et seq. The REA established the RUS as the 
body to administer financing to rural utilities.
    \49\ See Dairyland Power Coop. et al, v. Fed. Power Comm'n, 37 
F.P.C. 12, 27 (1967).
    \50\ As part of the Energy Policy Act of 2005 (``EPAct 2005''), 
Congress codified the previous interpretation by FERC in Dairyland, 
id., (affirmed by the D.C. Circuit Court in Salt River, 391 F. 2d 
470) that electric cooperatives that receive financing under the REA 
should be considered FPA 201(f) entities. At the same time, Congress 
also expanded the FPA 201(f) exemption to electric cooperatives that 
sell less than 4 million megawatt hours per year, even if those 
electric cooperatives do not receive any financing from the RUS. See 
Public Law 109-58, 1291, 119 Stat. 594, 985 (2005), amending FPA 
201(f) ``by striking ``political subdivision of a state,'' and 
inserting ``political subdivision of a State, an electric 
cooperative that receives financing under the Rural Electrification 
Act of 1936 (7 U.S.C. 901 et seq.) or that sells less than 4,000,000 
megawatt hours of electricity per year.''
---------------------------------------------------------------------------

b. Federally-Recognized Indian Tribes
    Federally-recognized Indian tribes that own or operate electric 
facilities are not described by FPA section 201(f), and thus would be 
subject to regulation as public utilities under the FPA. The Petition 
notes, however, that FERC and its predecessor, the FPC, and at least 
one court have determined such federally-recognized Indian tribes are 
to be treated as entities described in FPA section 201(f).\51\ To 
identify eligible Indian tribes, the Petition recommends that the 
Commission rely on determinations made by the Secretary of the 
Interior, periodically listed in the Federal Register, of Indian tribes 
to be recognized by the U.S. government pursuant to Section 104 of the 
Act of November 2, 1994.\52\
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    \51\ Per the Petition, see City of Paris, KY vs.  Fed. Power 
Comm'n, 399 F.2d 983 (D.C. Cir. 1968); Sovereign Power Inc., 84 FERC 
] 61,014 (1998); Confederated Tribes of the Warm Springs Reservation 
of Or., a Federally Recognized Indian Tribe, and Warm Springs Power 
Enterprises, a Chartered Enter. of the Confederated Tribes of the 
Warm Springs Reservation of Or., 93 FERC ] 61,182 at 61,599 (2000) 
(concluding that ``the Tribes are an instrumentality of the `United 
States, a State or any political subdivision of a state''' and that 
Warm Springs Power Enterprises, a Chartered Enterprise of the 
Tribes, was entitled to Tribes' Section 201(f) exemption.).
    \52\ Public Law 103-454, 108 Stat. 4791, 4792 (codified at 25 
U.S.C. 479a-1).
---------------------------------------------------------------------------

    Petitioners note that FERC's determination that such Indian tribes 
should be treated as FPA 201(f) entities was based on the fact that, in 
operating such electric facilities, the Indian tribes perform 
government functions--the funds generated by such electric operations 
would be used for governmental purposes and would decrease the need for 
federal funding. Additionally, Indian tribes are subject to Interior 
Department oversight. Finally, like the other government or government-
owned electric entities described in FPA section 201(f), the Indian 
tribes are tax exempt or ``not-for-profit'' entities.
2. Non-FPA 201(f) Electric Cooperatives
    The Petition also requests relief for the very small number of 
cooperatively-owned electric utilities that do not meet the criteria of 
FPA section 201(f), either because they do not receive funding from 
RUS, sell more than 4,000,000 megawatt hours of electricity in a given 
year, or are not an ``aggregated NFP

[[Page 51005]]

Electric Entity.'' \53\ FERC has estimated that there were 
approximately fifteen electric cooperatives (of more than 900) which do 
not meet the requirements set forth in FPA section 201(f).\54\ 
Petitioners request that the Commission recognize such cooperatives as 
``appropriate persons,'' in accordance with CEA sections 4(c)(1), 
4(c)(2)(B), and 4(c)(3)(K), for purposes of an exemption under CEA 
section 4(c)(6). Petitioners represent as a threshold matter that, 
regardless of whether an electric cooperative meets the specific 
criteria of FPA section 201(f), all cooperatively-owned electric 
utilities share certain distinguishing features--a common not-for-
profit public service mission and self-regulating governance model--
that form the underlying rationale for the FPA section 201(f) 
exemption.\55\
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    \53\ See Petition at 23. The Petitioners note that under various 
state laws, cooperatively owned electric utilities, or electric 
cooperatives, are sometimes called ``electric membership 
corporations'' or ``electric power associations.'' In addition, 
Petitioners note that under certain sections of tax laws, state 
public utility laws or regulations, the FPA or the FERC's 
regulations, electric cooperatives are sometimes called ``rural 
electric cooperatives'' or ``cooperatives providing electric 
services to consumers and farmers,'' or by similar, but not 
identical, entity names. See Petition at 2, note 5. In this Notice, 
as the Petitioners did in their Petition, the Commission uses the 
term ``electric cooperatives'' to encompass all of these entities, 
which are formed for the primary purpose of providing electric 
energy service to their owners/member customers on a not-for-profit 
basis, and which are treated as cooperatives under Federal tax laws.
    \54\ Statement of Cynthia A. Marlette, General Counsel of FERC, 
before the Committee on Agriculture, Subcommittee on Conservation, 
Credit, Energy, and Research, United States House of Representatives 
(July 30, 2008) (available at http://www.ferc.gov/eventcalendar/Files/20080730104611-Marlette.pdf). NRECA believes that, of its 
current members, the following six entities are non-FPA 201(f) 
electric cooperatives: Pacific Northwest Generating Cooperative 
(PNGC Power), Golden Spread Electric Cooperative, Old Dominion 
Electric Cooperative, Wabash Valley Power Association, Wolverine 
Power Cooperative, and Deseret Power Electric Cooperative.
    \55\ Similarly, to be treated as a ``cooperative'' under Federal 
tax law, regardless of 201(f) status, an electric cooperative must 
operate on a cooperative basis. See 26 U.S.C. 501(c)(12), 
1381(a)(2)(C). As explained by the United States Tax Court in the 
seminal case of Puget Sound Plywood, Inc. v.  Commissioner of 
Internal Revenue, operating on a cooperative basis means operating 
according to the cooperative principles of i) democratic member 
control, ii) operation at cost, and iii) subordination of capital. 
See 44 T.C. 305 (1965); see also Internal Revenue Manual Sec.  
4.76.20.4 (2006) (elaborating on the cooperative principles by 
explaining that each member of a cooperative has one vote, a 
cooperative must allocate any excess operating revenue to its 
members in proportion to the amount of business it did with each, 
and that members share their interest, risk, and burden to obtain 
services or benefits rather than invest as equity owners). 
Additionally, for any electric cooperative to be exempt from Federal 
income taxation pursuant to IRC 501(c)(12), it must collect annually 
``85 percent or more of [its] income * * * from members for the sole 
purpose of meeting losses and expenses.'' 26 U.S.C. 501(c)(12)(A). 
Accordingly, Petitioners argue that an electric cooperative, 
regardless of FPA section 201(f) status, lacks incentive or 
motivation to manipulate prices, disrupt market integrity, engage in 
fraudulent or abusive sales practices, or misuse customer assets 
because it: (1) Is a consumer cooperative; (2) is controlled by its 
members; (3) must operate at cost and ``not operate either for 
profit or below cost;'' (4) may not benefit its individual members 
financially; and (5) if exempt from Federal income taxation, must 
collect at least 85 percent of its income from members.
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    In analyzing whether an entity qualifies as an appropriate person 
under CEA section 4(c)(3), Petitioners note that past Commission 
determinations have focused on the financial strength and 
sophistication of the persons for whom relief is being provided. 
Petitioners also posit that CEA section 4(c)(3)(K) allows the 
Commission to consider the operations management qualification of the 
person or class of persons in relation to the exempted transactions, as 
well as the person's or class of person's ability to execute the 
exempted transactions without additional regulatory protection by the 
Commission. When considered in light of these determinative factors, 
Petitioners argue that source of financing or total electric energy 
sales are not meaningful factors for purposes of differentiating 
between electric cooperatives that are appropriate for an exemption 
from the CEA and those that are not.\56\
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    \56\ Petitioners argue that in promulgating CEA section 
4(c)(6)(C), ``Congress effectively makes the determination for the 
Commission that `entities described in FPA 201(f)' are `appropriate 
persons' entitled to the benefits of the exemptive order.'' Petition 
at 23. Thus, by extension, Petitioners argue that if non-FPA 201(f) 
electric cooperatives are at least as financially sound and 
operationally capable as those electric cooperatives described by 
FPA section 201(f), then they should also be considered appropriate 
persons.
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    First, the Petition argues that whether out of necessity due to 
insufficient Congressional appropriations, or by choice in order to 
find more appropriate or less expensive terms for certain needs, 
electric cooperatives may look to sources of financing beyond the RUS. 
Other nonprofit cooperative financing entities, such as the National 
Rural Utilities Cooperative Finance Corporation (``CFC'') or Co-
Bank,\57\ exist to supplement RUS financing or provide additional 
financing resources and terms not available through the RUS. 
Petitioners note that electric cooperatives always can choose to borrow 
from private lenders or self-finance infrastructure investments and 
operations with ongoing revenues and reserves. Eligibility for RUS 
financing does not speak to an electric cooperative's operational 
soundness or financial strength.
---------------------------------------------------------------------------

    \57\ Per the Petition, the CFC is a nonprofit cooperative entity 
formed in 1969 by NRECA's electric cooperative members. CFC provides 
access to financing to supplement the loan programs of the RUS. CFC 
is the largest non-governmental lender to America's rural electric 
systems, and nearly 200 electric cooperatives across the United 
States rely solely on CFC for financing. CFC has separately 
requested exemptive relief from the Commission for the swaps it 
enters into related to providing financing to its members' electric 
cooperatives. CoBank is a cooperative bank owned by electric 
cooperatives and agricultural cooperatives, and is a part of the 
Farm Credit Administration system.
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    Next, the Petition suggests that greater electric energy sales 
could result in greater financial strength. Petitioners note that while 
very few electric cooperatives historically have sold 4,000,000 
megawatt hours or more in a particular year, the success of the 
electric cooperative model means that there may be a small number of 
cooperatives in any particular year whose annual sales exceed the 
threshold.\58\ Furthermore, an electric cooperative's status under the 
FPA may fluctuate year-to-year depending on its annual megawatt sales, 
which always will fluctuate depending on usage trends, economic 
conditions, and weather patterns. Petitioners believe that Congress' 
policy decision to codify 4,000,000 megawatt hours per year as a 
threshold was based solely upon the fact that FERC, as well as other 
agencies, already used this level to identify ``small utilities,'' 
``small entities,'' or ``small businesses'' that should be afforded 
protection from the costs and regulatory burdens imposed on larger 
entities.\59\
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    \58\ Per the Petition's representation of data collected by 
NRECA, fewer than one percent of distribution cooperatives exceed 
the four million MWh annual sales threshold, as do approximately 24 
of 66 G&T cooperatives. The Commission understands that of those G&T 
cooperatives that exceed the sales threshold in a given year, the 
majority are still FPA 201(f) entities because they receive 
financing from RUS.
    \59\ See Petition at 35-36. Counsel for Petitioners also 
represent that EPAct 2005 was largely a response to the electrical 
blackouts in the northeast United States during 2003 that later were 
found to be attributable to generation and transmission failures of 
the largest electric utility providers. Thus, Congress' chief 
concern in expanding the 201(f) exemption for electric cooperatives 
was ensuring that entities with substantial generation and 
transmission capacity remained subject to the plenary jurisdiction 
of FERC. Per the Petition, Congress did not make a policy decision 
that the electric cooperatives selling 4 million megawatt hours or 
more per year required regulation under FPA 201(f) and, where EPAct 
2005 did give FERC additional discretionary jurisdiction over 
electric cooperatives, FERC has not chosen to exercise that 
discretionary authority to date. When FERC exercises its 
jurisdiction in certain instances, it allows non-FPA 201(f) electric 
cooperatives additional regulatory flexibility, subject to ``self-
regulation'' by such cooperatives' member/owner boards, 
distinguishing the not-for-profit electric sector from investor-
owned electric utilities. The very small number of electric 
cooperatives that do not meet the 4 million megawatts per year 
threshold at any point in time are, nonetheless, ``self-regulating 
entities,'' share the same cooperative governance structure, operate 
on a cooperative basis and are not-for-profit entities.

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[[Page 51006]]

    Thus, Petitioners argue that there is no implication under any of 
the FPA section 201(f) criteria for electric cooperatives that non-
201(f) electric cooperatives are more or less creditworthy or 
financially sound, or more or less deserving of operational deference 
or regulatory preference, than electric cooperatives that meet one of 
the FPA section 201(f) criteria.\60\
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    \60\ Petitioners note that non-FPA 201(f) electric cooperatives 
likely own more or larger generation and transmission assets, and 
therefore are arguably at least as financially sound and 
operationally qualified as electric cooperatives described in FPA 
section 201(f). Furthermore, these non-FPA 201(f) electric 
cooperatives may meet the financial criteria established in CEA 
section 4(c)(3)(F) for an ``appropriate person'' by having a net 
worth exceeding $1,000,000 or total assets exceeding $5,000,000.
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III. Commission Determinations

A. Scope of the Proposed Order

    In the exemptive order proposed herein (the ``Proposed 
Order''),\61\ the Commission is providing for a narrower scope of 
eligibility than requested by Petitioners. While the proposed exemptive 
relief is structured in a manner similar to the Petition's suggested 
approach and incorporates many of the same parameters,\62\ the Proposed 
Order uses different terminology to describe the pertinent categories 
of affected entities and transactions, and limits the exempted 
transactions to certain enumerated categories.\63\ The Proposed Order 
identifies (i) the entities eligible to rely on the exemption for 
purpose of entering into an exempt transaction (``Exempt Entities''); 
(ii) the agreement, contract, or transaction for which the exemption 
may be relied upon (``Exempt Non-Financial Energy Transactions''); and 
(iii) the provisions of the CEA that will continue to apply to Exempt 
Entities engaging in Exempt Non-Financial Energy Transactions. 
Accordingly, relief from the requirements of the CEA and Commission 
regulations provided in the Proposed Order will be available for only 
an Exempt Entity entering into an Exempt Non-Financial Energy 
Transaction with another Exempt Entity, subject to certain conditions.
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    \61\ The text of the Proposed Order is set forth in section IV 
of this Notice.
    \62\ See Petition Exhibit 3.
    \63\ The Commission believes that the open-ended relief sought 
by the Petitioners makes it difficult to evaluate the full range of 
transactions that would be subject to exemption and, thus, to 
conduct legitimate public interest and CEA purpose determinations as 
required under CEA section 4(c). As the Commission is not providing 
the categorical relief requested by Petitioners at this time, it 
considered the Petition's secondary requests to provide i) an 
additional category for ``trade options'' and/or ii) delegated 
authority to Commission staff to review and approve new categories 
of exempted transactions for purposes of being eligible for the 
relief provided herein. See supra note 26. Given Congressional 
intent that the Commission need not determine the nature of a 
product when providing 4(c) relief, the Commission does not believe 
it would be appropriate to provide specific relief to trade options 
as a category of transactions in the context of this proposed 
relief. See supra note 7 and accompanying text. While it is possible 
that the scope of the transactions eligible for the relief proposed 
herein may include transactions that otherwise would qualify as 
trade options, the Commission need not make such a finding in the 
context of the proposed 4(c) exemption. Rather, the Commission has 
determined to limit the scope of the proposed exemption to Exempt 
Non-Financial Energy Transactions, as described in the Proposed 
Order, and the Commission is requesting comment on this description. 
As for the Petitioner's request regarding delegated authority to 
CFTC staff, the Commission has never in the past delegated authority 
to staff to make ad-hoc 4(c) determinations, and does not propose 
such a delegation herein. Additionally, the Commission is not 
providing relief retroactive to the enactment of Dodd-Frank, as 
requested by Petitioners. The Commission specifically requests 
comment as to whether it should provide such relief, and as to 
whether such relief would be necessary to provide any relief beyond 
that which has already been available via the Commission's Dodd-
Frank implementation program, related exemptive orders, and staff 
no-action letters. The Commission also declines to propose, as was 
requested by Petitioners, that the transactions subject to the 
relief provided herein will not affect any entity's regulatory 
status under the CEA and Commission regulations. The Commission 
requests comment as to how the relief provided by the Proposed Order 
would be incomplete without such a provision and as to whether the 
Commission should include such a provision in the final exemptive 
order.
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1. Exempt Entities
    The Commission is proposing to include three general categories of 
electric utilities as Exempt Entities in the relief provided herein: 
(i) Government-owned electric utilities described by FPA section 
201(f); (ii) electric utilities owned by Federally-recognized Indian 
tribes, otherwise subject to regulation as public utilities under the 
FPA; and (iii) cooperatively-owned electric utilities, regardless of 
whether such utilities are described by FPA section 201(f), so long as 
they are treated as cooperative organizations under the Internal 
Revenue Code (``IRC'').\64\ Given the unique public service mission and 
governance structure of government, Indian tribe, and cooperatively-
owned electric utilities (as compared to investor-owned public 
utilities), the Commission believes that such Exempt Entities, when 
engaged in Exempt Non-Financial Energy Transactions, have less 
financial incentive to engage in market manipulation or other types of 
abusive trade practices that may implicate the public interest and/or 
purposes of the CEA and therefore are appropriate for section 4(c) 
relief.\65\
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    \64\ The Proposed Order also includes as an Exempt Entity any 
not-for-profit entity that is wholly owned, directly or indirectly, 
by any one or more of the entities included within the three general 
categories above.
    \65\ The potential for manipulation described here differs from 
the situation in CFTC v.  Dairy Farmers of America. In this case, a 
dairy cooperative was able to have a direct effect on a small 
illiquid spot cheese market that was a pricing component in the U.S. 
Department of Agriculture formula used to calculate milk prices 
under the Federal Milk Marketing Orders in an attempt to manipulate 
the price of Class III milk futures. The electric energy market 
situation is different because Exempt Entities do not report prices 
of Exempt Non-Financial Energy Transactions to indexes used to 
settle other derivative products that could benefit an Exempt Entity 
cooperative's members.
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    Generally, Exempt Entities are limited to nonfinancial commercial 
end users that operate on a not-for-profit basis. The Proposed Order 
defines Exempt Entities as those entities that do not meet the 
definition of a ``financial entity'' in CEA section 2(h)(7)(C). The 
purpose of this criterion is to prevent a cooperative that exists 
primarily in order to provide financing for its members, and thus 
enters into a significant number of derivative transactions to hedge 
financial price risks, such as movements in interest rates, from 
benefiting from the relief provided in the Proposed Order.\66\
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    \66\ The Commission also is proposing, in a separate 4(c) order, 
to extend the end-user exception found in CEA section 2(h)(7) to 
cooperatives that are financial entities as defined in CEA section 
2(h)(7)(C) (``Financial Cooperative 4(c) Order). The purpose of this 
4(c) relief is to extend the benefits of the end-user exception to 
cooperatives that meet the definition of a financial entity, but 
whose members otherwise would qualify for the end-user exception but 
choose to take advantage of the cooperative's low-cost access to 
financing. See 77 FR 41940 (July 17, 2012). The Commission notes, 
however, that for the policy reasons described herein as well as in 
the Financial Cooperative 4(c) Order, the extension of the end-user 
exception to financial cooperatives still requires reporting of swap 
transactions, whereas the relief provided in this Proposed Order 
does not.
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a. Electric Utilities Owned by Federal, State, or Local Government
    Pursuant to the mandate in CEA section 4(c)(6)(C) and subject to 
the determinations described in Section III.B below, the Commission is 
proposing to include as Exempt Entities in its Proposed Order all 
government-owned electric utilities that are described by FPA section 
201(f). FPA section 201(f) exempts from the plenary jurisdiction of 
FERC ``any agency, authority, or instrumentality of'' or ``any 
corporation which is wholly owned, directly or indirectly, by'' the 
federal government or a state or local government. These entities 
include, but are not limited to, all federal agency-owned electric 
generation and

[[Page 51007]]

transmission facilities,\67\ state-chartered electric utilities,\68\ 
utility boards or public utility districts formed under state or local 
law,\69\ and joint action or joint power agencies formed under state 
law to provide wholesale power supply and transmission services to 
member entities.\70\
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    \67\ See supra note 42.
    \68\ These utilities include, but are not limited to, entities 
such as the New York Power Authority.
    \69\ These utilities include, but are not limited to, municipal 
electric utilities, regardless of size.
    \70\ These utilities include government-owned public power and 
public utility districts such as an irrigation district organized 
under state law that generates electric energy during the course of 
supplying water.
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b. Electric Utilities Owned by an Indian Tribe
    Based on the determinations described in Section III.B below and 
pursuant to CEA section 4(c)(1), the Commission is proposing to include 
as Exempt Entities in its Proposed Order all electric facilities owned 
by federally-recognized Indian tribes that otherwise would be subject 
to FERC's plenary jurisdiction. For purposes of the Proposed Order, 
``federally-recognized'' means that the Indian tribe has been 
documented by the Secretary of the Interior in the Federal Register as 
having been recognized by the U.S. government, pursuant to section 104 
of the Act of November 2, 1994.\71\
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    \71\ Public Law 103-454, 108 Stat. 4791, 4792, as codified at 25 
U.S.C. 479a-1.
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    The Commission has determined that electric utilities owned by 
federally-recognized Indian tribes are no different substantively than 
government-owned electric utilities described immediately above for 
purposes of benefiting from the relief provided in the Proposed Order. 
Like government-owned electric utilities, electric utilities owned by a 
federally-recognized Indian tribe use funds generated from electric 
energy sales for purposes of running a tribal government. That is, 
instead of accruing profits for the benefit of private investors or 
shareholders, any excess operating revenues related to the generation 
or transmission of electricity are used by the Indian tribe to support 
the tribal governing body and reduce dependence on federal funding. 
Additionally, Indian tribes are tax-exempt or not-for-profit entities. 
Finally, the Commission notes that for many of the same reasons just 
noted, FERC has interpreted ``instrumentalities'' of government to 
include federally-recognized Indian tribes, thus treating electric 
facilities owned by these Indian tribes as FPA section 201(f) 
entities.\72\
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    \72\ See supra note 51.
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c. Electric Utilities Owned as Cooperative Organizations
    Pursuant to CEA section 4(c)(6)(C), and subject to the 
determinations described in Section III.B below, the Commission is 
proposing to include as Exempt Entities in its Proposed Order all 
cooperatively-owned electric utilities that are described by FPA 
section 201(f).\73\ Additionally, pursuant to the exemptive authority 
provided in CEA section 4(c)(1) and subject to the determination 
described in Section III.B below, the Commission is proposing to 
include as Exempt Entities all other electric cooperatives that are not 
described by FPA section 201(f).\74\ By reference to the IRC in the 
Proposed Order, an ``electric cooperative'' means a non-profit or not-
for-profit entity that is organized and continues to operate primarily 
to provide its members with electric energy services at the lowest cost 
possible and is taxed as an electric cooperative pursuant to IRC 
section 501(c)(12) or 1381(a)(2)(C).\75\ In order for an electric 
utility to be taxed as a cooperative, the electric utility must 
demonstrate that it operates in accordance with three principles: (i) 
Democratic member control; (ii) operation at cost (i.e., allocating any 
excess revenue, less cost of producing the revenue, among members in 
proportion to the amount of business done with each); and (iii) 
subordination of capital (i.e., no single contributor of capital to the 
cooperative can control the operations or receive most of the pecuniary 
benefits of operations, setting a cooperative apart from an 
investor).\76\
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    \73\ FPA section 201(f) exempts from the plenary jurisdiction of 
FERC any electric cooperative that either is funded by the RUS, 
sells less than 4,000,000 megawatt hours per year of electricity, or 
qualifies as an aggregated FPA 201(f) entity. An aggregated FPA 
201(f) entity consists of ``any corporation which is wholly owned, 
directly or indirectly, by any one or more [FPA 201(f) entity].'' 
These entities include Joint Action Agencies that are formed by 
constituent government-owned electric utilities described by FPA 
section 201(f).
    \74\ See infra Section III.B.4 for the Commission's analysis of 
why non-201(f) electric cooperatives are deemed to be appropriate 
persons for purposes of CEA section 4(c)(1) relief.
    \75\ 26 U.S.C. 501(c)(12), 1381(a)(2)(C). For purposes of the 
definition, the term ``electric cooperative'' includes a ``rural 
electric cooperative.'' The Commission understands that while not 
required for federal income tax status, many electric cooperatives 
are organized under state cooperative statutes as well. To the 
extent such laws impose requirements that conflict with those in IRC 
501(c)(12), state law governs without jeopardizing 501(c)(12) 
status. See Internal Revenue Manual Sec.  4.76.20.8 (2006).
    \76\ The term ``cooperative'' is not defined in IRC 501(c)(12) 
or 1381(a)(2)(C). Rather, common law has interpreted operation on a 
cooperative basis to mean the organization demonstrates the three 
principles noted above. See Puget Sound Plywood v.  Commissioner, 44 
T.C. 305, 307-308 (1965). Electric cooperatives receive tax-exempt 
status if they meet the additional criteria of receiving at least 85 
percent of revenue from their members for the sole purpose of 
meeting losses and expenses. See IRC 501(c)(12)(A). Otherwise, 
electric cooperatives are subject to federal income tax. See IRC 
1381(a)(2)(C); Rev. Rul. 83-135.
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    Exempt Entity electric cooperatives generally conform to one of two 
structures. First, a G&T cooperative generates or purchases and 
transmits electric energy at wholesale prices to its constituent 
distribution cooperatives, which are members/owners.\77\ Second, a 
distribution cooperative sells electric energy to member/owner retail 
customers.\78\ Both structures are consumer cooperatives, meaning that 
they were formed by consumers for the ``benefit of [such] members in 
their capacity as consumers.'' \79\ As noted above, Exempt Entities do 
not include cooperatives that qualify as financial entities pursuant to 
CEA section 2(h)(7)(C), regardless of whether they are recognized as 
FPA section 201(f) entities.\80\
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    \77\ G&T cooperatives may also transmit electric energy to other 
G&T cooperatives that are members based on ``generation capacity'' 
agreements as described by Petitioners. See supra Section II.B.2.
    \78\ Retail customers, in turn, use the electric energy to power 
everyday activities, whether commercial or residential in nature.
    \79\ See Puget Sound Plywood, 44 T.C. at 306. Alternatively, 
producer cooperatives, such as large farming cooperatives, exist for 
the ``benefit of the members in their capacity as producers.'' See 
id. The Commission notes that the public interest rationale for 
exempting consumer electric cooperatives articulated herein would 
not necessarily apply to other producer cooperatives, given 
differences in operational purposes and motivations behind forming 
such cooperatives.
    \80\ Additionally, financial cooperatives are not tax-exempt 
entities pursuant to IRC 501(c)(12). See Internal Revenue Manual 
Sec.  4.76.20.5 (2006). The Commission intends for financial 
cooperatives that finance electric cooperatives, such as the CFC, to 
rely on the exemptive relief provided in the recently-proposed 
financial cooperative 4(c) order. See supra note 66.
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2. Exempt Non-Financial Energy Transactions
    The Proposed Order defines Exempt Non-Financial Energy Transactions 
as those agreements, contracts, or transactions entered into between 
Exempt Entities primarily in order ``to satisfy existing or anticipated 
contractual obligations to facilitate the generation, transmission, 
and/or delivery of electric energy service to customers at the lowest 
cost possible, and the agreement, contract, or transaction is intended 
for making or taking physical delivery of the commodity upon which the 
agreement, contract, or transaction is based.'' \81\

[[Page 51008]]

Exempt Non-Financial Energy Transactions are limited to six categories 
of agreements, contracts, or transactions, as described in further 
detail in the Proposed Order,\82\ which facilitate: (i) The generation 
of electric energy by an Exempt Entity, including fuel supply; (ii) the 
purchase or sale and transmission of electric energy by/to an Exempt 
Entity; and (iii) compliance with electric system reliability 
obligations applicable to the Exempt Entity and its facilities or 
operations.
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    \81\ The Petition asserts that the purpose of all transactions 
for which relief is sought (as described therein) must be `` `to 
hedge or mitigate commercial risks' (as such phrase is used in CEA 
Section 2(h)(7)(A)(ii)).'' See Petition at 4. The Commission 
believes, however, that based on the general descriptions and 
accompanying examples of Electric Operations-Related Transactions 
provided in Petition, some types of transactions may not be 
agreements, contracts, or transactions that the Commission 
traditionally has viewed to ``hedge or mitigate commercial risk'' as 
such phrase is used in CEA section 2(h)(7)(A)(ii). Due to the 
breadth and vagueness of some of the Petition's descriptions, it is 
unpractical for the Commission to identify every manifestation of an 
Electric Operations-Related Transaction that does not come within 
the Commission's jurisdiction, although it has attempted to do so to 
the extent that the Commission has already made an affirmative 
determination elsewhere as to the nature of a product described in 
the Petition. See infra notes 86-90 and accompanying text. In any 
case, in order to provide Exempt Entities with regulatory certainty 
pursuant to CEA section 4(c), the Commission is defining Exempt Non-
Financial Energy Transactions to include all agreements, contracts, 
or transactions entered into for the primary purpose of satisfying 
existing or anticipated contractual obligations to fulfill an Exempt 
Entity's public service mission that are intended for making or 
taking physical delivery of the underlying commodity. The Commission 
is seeking comments on the merits to this approach in defining 
Exempt Non-Financial Energy Transactions.
    \82\ The descriptions of the categories of exempted transactions 
in the Proposed Order are based on the Commission's understanding of 
the transaction types as commonly known to the electric industry, as 
informed by the descriptions provided in the Petition and the 
Commission's past experience in these markets. While the categories 
are identified with the same terminology used in the Petition, the 
Commission notes that these categories are not described in 
identical terms and therefore do not necessarily describe the same 
scope of transactions as contemplated in the Petition for exemption. 
The Commission understands that many of the terms used to identify 
categories of transactions in the Petition are terms of art, 
commonly understood by the electric energy industry (including by 
Exempt Entities).
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    When combined with the requirements for Exempt Entities described 
above, the Commission believes that Exempt Non-Financial Energy 
Transactions, as defined under the Proposed Order, will not be used for 
speculative purposes. That is, Exempt Entity counterparties to Exempt 
Non-Financial Energy Transactions must contemplate ``delivery'' of the 
underlying good or service at the time they enter into the agreement, 
contract, or transaction, whether that be for electric energy, 
generation capacity, access to transmission lines, fuel, or some 
combination of the foregoing.\83\ Furthermore, these transactions 
generally are not used by Exempt Entities for the primary purpose of 
hedging fluctuations in the price of electric energy or any other 
commodity related to the generation, transmission, and/or delivery of 
electric energy to customers.\84\ Finally, the majority of Exempt Non-
Financial Energy Transactions are not suitable for trading on an 
exchange such as a registered DCM or SEF due to their highly bespoke 
nature, and cannot include transactions based on, derived from, or 
referencing any financial commodity or any metal, agricultural, crude 
oil or gasoline commodity that cannot be used as fuel to generate 
electric energy. For these reasons, and for the reasons discussed in 
the 4(c) analysis provided in Section III.B below, the Commission 
believes that these transactions are unlikely to have an impact on 
price discovery or the functioning of markets regulated by the 
Commission, and thus are appropriate for conditional relief from the 
requirements of the CEA and regulations thereunder, pursuant to CEA 
section 4(c).
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    \83\ Although some agreements may be settled through a book-out 
transaction, the transaction may never be entered into for 
speculative purposes.
    \84\ A key component of bona fide hedging, as defined in the 
Commission's regulations, is reducing the risk of fluctuations in 
price. In contrast, Exempt Non-Financial Energy Transactions 
primarily are used for making or taking delivery of electric energy 
in the physical marketing channel.
---------------------------------------------------------------------------

    The unique nature of the electric energy industry, including the 
unique nature of the not-for-profit utility structure, influenced the 
Commission's choice of the transactions within the scope of the 
exemption in the Proposed Order. Supply of reliable, affordable 
electric energy has long been constrained by a limited amount of 
generation and transmission capacity, particularly in rural regions, 
that is capable of meeting peak demand. Unlike many physical 
commodities, electric energy is not capable of being purchased in large 
commercial quantities ahead of time, delivered, and stored for later 
consumption or use. That is, electric energy must be used or consumed 
on an as-needed basis.
    Demand, on the other hand, can be subject to unpredictable 
fluctuations due to emergency situations and changes in weather 
patterns, usage trends, and larger macroeconomic conditions. Thus, 
electric utilities, including Exempt Entities, negotiate highly 
customized commercial arrangements in order to fulfill these constantly 
fluctuating retail electric energy needs while still complying with 
national and regional environmental and reliability standards. Each 
category of Exempt Non-Financial Energy Transactions described in the 
Proposed Order represents a component of these larger bespoke 
commercial transactions used to fulfill an Exempt Entity's public 
service mission.\85\
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    \85\ Each category represents a factor in the ultimate price 
paid by retail customers for electric energy. For example, 
``generation capacity'' transactions represent the cost component of 
acquiring and maintaining the generation assets used to produce the 
electric energy. ``Electric energy delivered'' represents the actual 
cost of using the generation assets to produce the electric energy.
---------------------------------------------------------------------------

    The Commission notes that not every transaction described by the 
Petition is being included in the Commission's definition of Exempt 
Non-Financial Energy Transaction. Due to the Commission's recent joint 
final rule and interpretation with the SEC in which it further defined 
what is (and is not) a swap (``Products Release''),\86\ the Commission 
believes it would not be appropriate to provide 4(c) relief from the 
requirements of the CEA and Commission regulations thereunder for 
certain transactions that are not swaps.\87\
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    \86\ 77 FR 48208 (August 13, 2012).
    \87\ The Commission has determined to interpret the forward 
exclusion from the swap definition consistently with the forward 
exclusion from the ``future delivery'' definition. Id. at 48227. 
Therefore, the forward exclusion from the swap definition applies 
equally to the forward exclusion from the ``future delivery'' 
definition. See id. at 48233, note 271.
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    Specifically, the Commission notes that, consistent with an example 
provided in the Products Release, the example of a Fuel Delivered 
transaction provided in Exhibit B of the Petition would be covered by 
the forward exclusion from the swap definition.\88\ Additionally, the 
Commission notes that, consistent with the general description provided 
in the Products Release, agreements, contracts, and transactions 
involving the category of Environmental Rights, Allowances or 
Attributes as specifically described by the Petition are covered by the 
forward exclusion from the swap definition.\89\ Accordingly, while 
these agreements, contracts, and transactions are not covered by the 
relief in the Proposed Order, they nonetheless are not subject to the 
requirements of the CEA and Commission regulations thereunder otherwise 
applicable to swaps, such as

[[Page 51009]]

clearing, trade execution, and reporting.\90\
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    \88\ Compare Petition Exhibit 2 at 3 with 77 FR 48236.
    \89\ Compare Petition at 12 and Petition Exhibit 2 at 6 with 77 
FR 48233-234.
    \90\ However, any agreement, contract, or transaction that is a 
swap referencing one of these agreements, contracts, and 
transactions may be subject to the jurisdiction of the CEA (e.g., an 
option or other swap on or related to the price of an environmental 
allowance).
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    Finally, the descriptions of the categories of Exempt Non-Financial 
Energy Transactions in the Proposed Order do not constitute official 
Commission determinations as to those transactions' legal status as a 
product subject to the jurisdiction of the CEA.\91\ To the extent 
overlap exists between transactions described as being subject to the 
forward exclusion from the swaps definition in the Products Release and 
transactions described by the categories of Exempt Non-Financial Energy 
Transactions in the Proposed Order, the Commission is requesting public 
comment as to whether the Proposed Order should provide relief for such 
transactions.
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    \91\ As noted above, CEA section 4(c) does not compel the 
Commission to make such a determination prior to issuing 4(c) 
relief. See supra note 7 and accompanying text. In contrast, and in 
addition to providing per se determinations as to the product 
classification of certain transactions, the Products Release 
provides interpretive guidance as to how the Commission would 
analyze certain categories of transactions for purposes of 
determining whether a particular transaction is a swap. Accordingly, 
certain transactions covered by the categories of Exempt Non-
Financial Energy Transactions in the Proposed Order may not be 
swaps. See, e.g., 77 FR 48238 (noting that the Commission will 
interpret a ``full requirements'' contract with embedded volumetric 
optionality as a forward and not an option if the contract exhibits 
the features described in the Products Release in section 
II.B.2.(b)(ii)).
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3. Conditions
    Under the Proposed Order, Exempt Entities would remain subject to 
certain conditions. First, the Commission's general anti-fraud, anti-
manipulation, and enforcement authority found in CEA sections 
2(a)(1)(B), 4b, 4c(b), 4o, 6(c), 6(d), 6(e), 6c, 6d, 8, 9 and 13, and 
Commission rules 32.4 and Part 180, which have application to both 
derivative and cash market transactions, will still apply. This 
condition will allow the Commission to initiate enforcement proceedings 
against Exempt Entities found to be engaged in manipulative, 
fraudulent, or otherwise abusive trading schemes when executing Exempt 
Non-Financial Energy Transactions with other Exempt Entities. 
Additionally, the Commission reserves its authority to inspect the 
books and records of Exempt Non-Financial Energy Transactions already 
kept in the normal course of business pursuant to the Commission's 
regulatory inspection authorities, in the event that circumstances 
warrant the need to gain greater visibility with respect to Exempt Non-
Financial Energy Transactions as they relate to Exempt Entities' 
overall market positions and to ensure compliance with the terms of the 
Proposed Order.

B. CEA Section 4(c) Considerations

    The Commission is issuing the Proposed Order pursuant to authority 
found in CEA sections 4(c)(1) and 4(c)(6), among other reasons, because 
it believes that the proposed exemption will promote responsible 
economic or financial innovation and fair competition. In addition to 
criteria found in those provisions, both sources of exemptive relief 
require the Commission to make certain determinations based on criteria 
found in section 4(c)(2), as well.\92\ Accordingly, the Commission 
considers and proposes to determine that: (i) CEA section 4(a) should 
not apply to the transactions eligible for the proposed exemption (as 
transacted by the entities eligible for the proposed exemption), (ii) 
providing section 4(c) relief from the CEA for Exempt Non-Financial 
Energy Transactions (as entered into between Exempt Entities) is 
consistent with the public interest and the purposes of the CEA, (iii) 
Exempt Entities are ``appropriate persons'' within the meaning of the 
term as defined in CEA section 4(c)(3), and (iv) the proposed exemption 
will not have a material adverse effect on the ability of the 
Commission or any contract market to discharge its regulatory or self-
regulatory duties under the CEA.
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    \92\ The Commission interprets the phrase, ``the Commission 
shall, in accordance with [CEA section 4(c)(1) and 4(c)(2)], exempt 
from the requirements of [the CEA] * * *,'' to mean that the 
Commission must make the determinations required under CEA sections 
4(c)(1) and 4(c)(2) prior to providing the mandated relief.
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1. Responsible Economic or Financial Innovation and Fair Competition
    The Commission believes that the exemption provided in the Proposed 
Order will promote financial innovation in electric energy markets 
facilitated by government and cooperatively-owned utilities. Government 
and cooperatively-owned electric utilities are not-for-profit entities 
whose sole purpose and mission is ``to provide reliable electric energy 
to retail electric customers every hour of the day and every season of 
the year, keeping costs low and supply predictable, while practicing 
cost-effective environmental stewardship.'' \93\ The consumer-as-owner 
cooperative model of electric utility, in partnership with municipal 
utilities and federal power agencies, has proven to be well-suited in 
developing innovative solutions to a complex array of issues related to 
extending electric energy generation and transmission resources into 
geographic areas of the United States where economies of scale do not 
exist, particularly those rural areas where traditional investor-owned 
utilities have chosen not to invest.\94\ In order to meet these 
electric energy challenges, however, the Exempt Entity business model 
has depended on a flexible operating environment, facilitated over time 
by other regulatory relief such as the exemption from FERC's plenary 
jurisdiction provided by FPA section 201(f).
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    \93\ Petition at 22.
    \94\ For instance, investor-owned, private utilities lacked a 
profit incentive early on to invest the vast sums of capital 
necessary to expand electric energy service into rural areas where 
the requisite infrastructure was not already in place. With support 
from the RUS, as established under the FPA, electric cooperatives 
were first established in order to serve these rural communities.
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    Due to factors largely beyond the control of Exempt Entities, the 
production, distribution, and usage needs of each Exempt Entity are 
constantly changing and have the potential to create the substantial 
commercial risk of not having enough generation, transmission, or 
distribution capacity for Exempt Entities to meet peak demand. Normally 
without the benefit of size and customer density, Petitioners contend 
that Exempt Entities have evolved to rely largely on each other in 
order to fulfill their public service mission of providing electric 
energy to their member-owners and retail customers at the lowest cost 
possible.\95\ The transactions listed in the Proposed Order reflect 
this type of innovation. Going forward, due to the limitations of 
standardized derivative contracts in providing the same type of highly 
customized resources to unique energy needs, it is important that 
Exempt Entities continue to have the flexibility to negotiate 
innovative new arrangements bilaterally for the purpose of achieving 
their mission.
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    \95\ For example, many G&T cooperatives are formed exclusively 
by distribution cooperatives for the purpose of providing each 
distribution cooperative with its full requirements.
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    Additionally, the Commission notes that, under current Commission 
regulations and guidance, it is unclear whether all Exempt Entities 
would qualify as eligible contract participants (``ECPs''), as such 
term is defined under CEA section 1a(18).\96\ Therefore, absent

[[Page 51010]]

relief such as that proposed herein, there is a risk that some Exempt 
Non-Financial Energy Transactions meeting the definition of a swap that 
involve non-ECP counterparties could not be traded away from a 
designated contract market.\97\ As described elsewhere in this release, 
Exempt Entities engage in Exempt Non-Financial Energy Transactions with 
one another on only a bilateral basis because such transactions are not 
replicable on an exchange (whether due to transaction size, customized 
terms, or other reasons). Therefore, the Commission is proposing the 
exemption in the Proposed Order to ensure that Exempt Entities have the 
regulatory certainty necessary to continue negotiating highly 
customized, physically-settled agreements, contracts, and transactions 
that serve their unique public service mission of providing reliable, 
affordable electric energy to customers.
---------------------------------------------------------------------------

    \96\ 7 U.S.C. 1a(18). In a recent final interpretive rule 
further defining entities under the CEA, as amended by the Dodd-
Frank Act (``Entities Release''), the Commission declined to 
recognize certain entities such as not-for-profit natural gas 
utilities as having per se ECP status. See Further Definition of 
``Swap Dealer,'' ``Security-Based Swap Dealer,'' ``Major Swap 
Participant,'' ``Major Security-Based Swap Participant'' and 
``Eligible Contract Participant,'' 77 FR 30596, 30657 (May 23, 
2012). The Commission noted that it was, however, considering 
granting relief to FPA section 201(f) entities, pursuant to new 
authority under CEA section 4(c)(6), which ``[might] address the 
concerns of some commenters'' such as entities similarly situated to 
the utilities represented by Petitioners. See id. The relief 
provided in the Proposed Order is consistent with the Commission's 
Entities Release.
    \97\ See CEA section 2(e).
---------------------------------------------------------------------------

    The Commission also believes that the relief provided in the 
Proposed Order will not distort the competitive landscape. First, the 
transactions covered by the Proposed Order relate, in many instances, 
to longstanding and exclusive agreements between Exempt Entities. As 
such, the Commission does not believe that granting an exemption from 
the requirements of the CEA either would change the nature of these 
transactions, or cause an Exempt Entity to enter into an arrangement 
with another Exempt Entity instead of an investor owned utility or some 
other counterparty solely because the agreement would be covered by the 
exemption in the Proposed Order. The benefits of the relief provided in 
the Proposed Order to government utilities and electric cooperatives 
will maintain the current competitive landscape, thus permitting Exempt 
Entities to continue using Exempt Non-Financial Energy Transactions to 
fulfill their public service mission, as opposed to providing an unfair 
advantage to one group over another group.\98\
---------------------------------------------------------------------------

    \98\ The Commission notes that certain non-Exempt Entity 
electric utilities also may qualify for the end-user exception from 
the clearing and trade execution requirements for swaps under CEA 
section 2(h)(7) when engaged in bona fide hedging transactions. See 
7 U.S.C. 2(h)(7)-(8).
---------------------------------------------------------------------------

    The CFTC is requesting comment on whether the Proposed Order may 
foster both financial or economic innovation and fair competition.
2. Applicability of CEA Section 4(a)
    The Commission does not believe that CEA section 4(a), the 
exchange-trading requirement for futures contracts, should apply to 
Exempt Non-Financial Energy Transactions as defined in the Proposed 
Order. When transacted between Exempt Entities, these transactions are 
highly negotiated and bespoke in nature, cater specifically to the 
Exempt Entities' respective electricity, fuel, or other needs, and are 
intrinsically related to the Exempt Entities' public-service mission. 
Accordingly, the Commission does not view Exempt Non-Financial Energy 
Transactions as being suitable for on-exchange trading, in large part 
because, as noted above, these transactions and markets are unlikely to 
have an impact on price discovery or the functioning of markets 
regulated by the Commission. Thus, CEA section 4(a) should not apply.
3. Public Interest and the Purposes of the CEA
    Exempting certain physical transactions between entities described 
in FPA section 201(f), and certain other electric cooperatives, from 
the provisions of the CEA and the regulations there under, subject to 
certain anti-fraud, anti-manipulation, and recordkeeping conditions, is 
consistent with public interest and the purposes of the CEA for the 
reasons discussed below.
a. Public Interest
    CEA section 3(a) describes Congress' findings as to certain 
national public interests facilitated by transactions subject to the 
Act. These public interests include ``providing a means for managing 
and assuming price risks, discovering prices, or disseminating pricing 
information through trading in liquid, fair and financially secure 
trading facilities.'' \99\
---------------------------------------------------------------------------

    \99\ CEA 3(a), 7 U.S.C. 5(a).
---------------------------------------------------------------------------

    Given the unique nature of each Exempt Non-Financial Energy 
Transaction conducted between Exempt Entities, such transactions are 
generally non-fungible and therefore cannot be traded as standardized 
products on an exchange. Accordingly, the universe of Exempt Non-
Financial Energy Transactions generally occurs between Exempt Entities, 
thus constituting a mostly closed-loop of bilateral transactions. These 
bilateral transactions do not, by and large, face markets in which non-
Exempt Entities such as investor-owned utilities engage in similar 
transactions, and therefore pose little (if any) threat of negatively 
affecting the liquidity, fairness, or financial security of trading 
derivative products on a registered designated contract market or swap 
execution facility in a material way.
    Exempt Non-Financial Energy Transactions, as they are defined and 
conditioned in the Proposed Order, are not susceptible to being used as 
a means for ``assuming price risk,'' or speculative activity. Rather, 
Exempt Entities may engage in these transactions for purposes of 
``managing'' commercial risks that arise from electric operations in 
which the Exempt Entity engages to fulfill its public service mission 
of providing the most affordable and reliable electric energy possible 
to its members. Most of these commercial risks, however, are not 
directly related to fluctuations in the price of a commodity. Rather, 
Exempt Entities' main concern is a possible inability to satisfy 
contractual obligations to supply electric energy service to customers, 
which may arise from somewhat unpredictable fluctuations in demand for 
electric energy. These fluctuations, in turn, make it difficult for 
Exempt Entities to forecast their exact needs for generation and 
transmission capacity, the exact amount of fuel to be used for the 
generation of electric energy, and related activities necessary to 
facilitate the Exempt Entity's public service mission. Exempt Non-
Financial Energy Transactions generally use variable pricing, as 
opposed to fixed pricing, meaning that they are entered into primarily 
to ensure that Exempt Entities are able to meet their production, 
transmission, and/or distribution obligations, as opposed to serving a 
traditional hedging function against the risk of price fluctuations of 
electricity or some other commodity.
    It is unlikely that an exchange could or would model a standardized 
derivative contract to duplicate the highly-customized economic terms 
of a bilaterally-negotiated Exempt Non-Financial Energy Transaction. 
Accordingly, such transactions between Exempt Entities are not 
susceptible to serving a price discovery function for any broader 
market or markets. A market participant seeking pricing information for 
a product or transaction involving the same underlying commodity would 
look to a standardized product or contract traded

[[Page 51011]]

on a regulated exchange involving that commodity.\100\
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    \100\ The Commission notes that FERC recently has proposed 
requiring entities described in FPA 201(f) to be subject to limited 
reporting requirements concerning the availability and prices of 
wholesale electric energy. In EPAct 2005, Congress added Section 220 
to the FPA (16 U.S.C. 824t) directing FERC to ``facilitate price 
transparency in markets for the sale and transmission of electric 
energy in interstate commerce'' with ``due regard for the public 
interest, the integrity of those markets, fair competition, and the 
protection of consumers.'' See Electricity Market Transparency 
Provisions of Section 220 of the Federal Power Act, 135 FERC ] 
61,053 at PP 21-23 (Notice of Proposed Rulemaking) (2011) 
(collection of information from ``any market participant'' 
interpreted to include entities described in FPA 201(f)). The 
Commission specifically seeks comment on whether, in light of this 
proposal, the relief provided in the Proposed Order should be 
revised in the future to require reporting to an SDR for certain 
transactions.
---------------------------------------------------------------------------

    The CFTC is requesting comment on whether the Proposed Order is 
consistent with the public interest.
b. Purposes of the CEA
    Under section 3(b), in order to foster the public interests, it is 
the purpose of the CEA ``to deter and prevent price manipulation or any 
other disruptions to market integrity; to ensure the financial 
integrity of all transactions subject to [the CEA] and the avoidance of 
systemic risk; to protect all market participants from fraudulent or 
other abusive sales practices and misuses of customer assets; and to 
promote responsible innovation and fair competition among boards of 
trade, other markets and market participants.'' \101\ The Commission 
believes that the exemptive relief provided in the Proposed Order is 
consistent with these purposes.\102\
---------------------------------------------------------------------------

    \101\ CEA 3(b); 7 U.S.C. 5(b).
    \102\ As noted in section III(B)(1) above, the Commission 
believes that the exemption will promote financial innovation and 
fair competition.
---------------------------------------------------------------------------

    Exempt Entities are either government or cooperatively-owned 
electric utilities organized under Federal tax laws as nonprofit or 
not-for-profit entities. All Exempt Entities share a public service 
mission of providing reliable electric energy to retail electric 
customers at all times, keeping costs low and supply predictable, while 
practicing cost-effective environmental stewardship. Elected or 
appointed government officials or citizens, or cooperative members or 
consumers, are directly involved in the day-to-day governance and 
management of an Exempt Entity's facilities and operations. There are 
no shareholders or outside investors to profit from the Exempt Non-
Financial Energy Transactions, and any revenues accruing from 
operational risk management activities related to the electric 
facilities and operations are used to reduce the cost of electric 
service provided to cooperative members and retail customers.
    Accordingly, the Commission believes that Exempt Non-Financial 
Energy Transactions between Exempt Entities are less vulnerable to 
fraudulent or manipulative trading activity. Congress affirmatively 
recognized this in the context of wholesale electric energy markets 
when it exempted government and cooperatively-owned electric utilities 
from FERC's plenary jurisdiction under FPA section 201(f).\103\ 
Furthermore, the Proposed Order retains the Commission's general anti-
fraud, anti-manipulation, and enforcement authority,\104\ and all 
Exempt Entities, regardless of status under FPA section 201(f), remain 
subject to FERC's market manipulation authority.\105\ Therefore, the 
relief provided in the Proposed Order does not interfere with the 
Commission's ability to police markets for manipulation and fraudulent 
trade practices.
---------------------------------------------------------------------------

    \103\ See supra notes 45-50 and accompanying text for a 
discussion of the FPC's findings in its Dairyland decision, affirmed 
by the federal court in Salt River, explaining the underlying 
rationale for exempting non-investor owned public utilities from the 
plenary jurisdiction of the FPC.
    \104\ See CEA sections 2(a)(1)(B), 4b, 4c(b), 4o, 6(c), 6(d), 
6(e), 6c, 6d, 8, 9 and 13, and Commission rules 32.4 and Part 180.
    \105\ See FPA 222v; 16 U.S.C. 824v.
---------------------------------------------------------------------------

    Finally, the Commission does not view Exempt Non-Financial Energy 
Transactions between Exempt Entities as posing a systemic risk to the 
financial integrity or stability of markets. By definition, Exempt 
Entities do not consist of interconnected ``financial institutions'' 
subject to prudential regulation because they are ``systemically 
important.'' \106\ Exempt Non-Financial Energy Transactions do not 
involve financial market professionals, intermediaries, or any other 
entity registered with the Commission. Rather, Exempt Non-Financial 
Energy Transactions involve counterparty credit risk between only 
Exempt Entities, which share a common not-for-profit public service 
mission and are obligated to pursue operational, not financial, 
performance mandates. The Commission does not believe that imposing the 
requirements of the CEA on these transactions would reduce systemic 
risk or bolster the financial stability and soundness of the markets 
that the Commission does regulate. Accordingly, the Commission does not 
view the relief provided in the Proposed Order as being contrary to 
this purpose of the CEA.
---------------------------------------------------------------------------

    \106\ Additionally, Exempt Entities do not consist of 
``financial entities'' as the term is defined in CEA 2(h)(7)(C)(i).
---------------------------------------------------------------------------

    The CFTC is requesting comment on whether the Proposed Order is 
consistent with the purposes of the CEA.
4. Appropriate Persons
    Exempt Entities entering into Exempt Non-Financial Energy 
Transaction are ``appropriate persons'' for purposes of satisfying CEA 
section 4(c)(2) for different reasons, depending on the type of 
electric utility and the corresponding section of the CEA pursuant to 
which the relief in the Proposed Order is being granted. The Commission 
believes that Congress, in enacting CEA section 4(c)(6)(C), implicitly 
identified entities described by FPA section 201(f) as appropriate 
persons for purposes of qualifying for an exemption pursuant to CEA 
section 4(c)(6); otherwise, Congress would not have mandated that the 
Commission ``shall * * * exempt'' such entities upon making the 
required findings.\107\
---------------------------------------------------------------------------

    \107\ Alternatively, the Commission notes that many FPA section 
201(f) entities are government-owned or sponsored, and therefore 
would qualify as appropriate persons under CEA section 4(c)(3)(H): 
``Any governmental entity * * * or political subdivision thereof, * 
* * or any instrumentality, agency, or department of any of the 
foregoing.''
---------------------------------------------------------------------------

    Next, for the reasons just noted, the Commission believes that 
federally-recognized Indian tribes that own electric facilities are 
analogous to government entities that sponsor electric facilities, and 
therefore qualify as appropriate persons pursuant to CEA section 
4(c)(3)(H).\108\
---------------------------------------------------------------------------

    \108\ See id.
---------------------------------------------------------------------------

    Finally, the Commission believes that non-FPA 201(f) electric 
cooperatives are appropriate persons for the reasons articulated in the 
Petition with respect to such cooperatives. Under CEA section 
4(c)(3)(K), the Commission may determine other persons not enumerated 
elsewhere in section 4(c)(3) to be appropriate in light of their 
financial or other qualifications, or the applicability of appropriate 
regulatory protections. As previously noted, the Commission believes 
that Congress implicitly deemed FPA 201(f) entities to be appropriate 
persons, thus indicating that FPA 201(f) entities have the requisite 
financial soundness and operational capabilities to execute 
transactions that are exempt from the requirements of the CEA.
    For the purposes of a 4(c) exemption, the Commission believes that 
there is no material difference in an electric cooperative's financial 
soundness or operational capability based upon

[[Page 51012]]

whether or not the electric cooperative meets the criteria of FPA 
section 201(f).\109\ As Petitioners note, an electric cooperative that 
receives financing from a source other than the RUS or sells more than 
4,000,000 megawatt hours of electricity per year is at least as 
financially sound and operationally qualified as electric cooperatives 
described in FPA section 201(f).\110\ The Commission notes that non-
201(f) electric cooperatives arguably are more financially sound and 
operationally capable, as they likely maintain greater generation and 
transmission assets capable of facilitating the excess electric energy 
sales.\111\ Additionally, non-FPA 201(f) electric cooperatives that 
sell more than the threshold amount of electric energy per year often 
are in a position to benefit from better financing terms than those 
offered by the RUS based on having greater financial assets to post as 
collateral.
---------------------------------------------------------------------------

    \109\ As previously noted, non-FPA 201(f) electric cooperatives 
are governed by the same public service mission as FPA 201(f) 
electric cooperatives (i.e., providing members with electric energy 
at the lowest cost possible).
    \110\ In expanding the FPA 201(f) exemption to include RUS-
financed electric cooperatives, Congress went a step further in 
EPAct 2005 by also including electric cooperatives that sold less 
than 4,000,000 megawatt hours of electricity per year. According to 
counsel for Petitioners, this provision was meant to capture certain 
small, distribution-only cooperatives that did not receive financing 
from the RUS.
    \111\ Alternatively, certain non-FPA 201(f) electric 
cooperatives may qualify as appropriate persons based on their net 
worth exceeding $1,000,000 or total assets exceeding $5,000,000. See 
CEA section 4(c)(3)(F).
---------------------------------------------------------------------------

    The CFTC is requesting comment as to whether the Exempt Entities 
identified in the Proposed Order are appropriate persons.
5. Ability to Discharge Regulatory or Self-Regulatory Duties
    The exemptive relief contained in the Proposed Order will not have 
a material adverse effect on the ability of the Commission or any 
contract market to discharge its regulatory or self-regulatory duties 
under the CEA. Nothing in the Proposed Order will prevent the 
Commission or any contract market from carrying out regulatory or self-
regulatory duties for markets in a commodity that may also be involved 
in an Exempt Non-Financial Energy Transaction. As previously discussed, 
given the bespoke nature of these transactions, they are not connected 
to the pricing and market characteristics of other related derivative 
products that trade on exchange. The Commission is less concerned about 
the regulatory oversight of Exempt Entities as they are ``effectively 
self-regulating'' bodies subject to government or cooperative-member 
management.
    The CFTC is requesting comment as to whether the Proposed Order 
will have a material adverse effect on the ability of the Commission or 
any contract market to discharge its regulatory or self-regulatory 
duties under the CEA.

IV. Proposed Order

    The Commission has determined, pursuant to Commodity Exchange Act 
(``CEA'') sections 4(c)(1) and 4(c)(6), to exempt from all requirements 
of the CEA and Commission regulations issued there under any Exempt 
Non-Financial Energy Transaction entered into solely between Exempt 
Entities, subject to the following definitions and conditions:
    A. Exempt Entity shall mean (i) any government-owned electric 
facility recognized under Federal Power Act (``FPA'') section 201(f), 
16 U.S.C. 824(f); (ii) any electric facility otherwise subject to 
regulation as a ``public utility'' under the FPA that is owned by an 
Indian tribe recognized by the U.S. government pursuant to section 104 
of the Act of November 2, 1994, 25 U.S.C. 479a-1; (iii) any 
cooperatively-owned electric utility, regardless of status pursuant to 
FPA section 201(f), so long as the utility is treated as a 
``cooperative'' organization under Internal Revenue Code section 
501(c)(12) or 1381(a)(2)(C), 26 U.S.C. 501(c)(12), 1381(a)(2)(C), and 
exists for the primary purpose of providing electric energy service to 
its member/owner customers at the lowest cost possible; or (iv) any 
not-for-profit entity that is wholly owned, directly or indirectly, by 
any one or more of the foregoing. The term ``Exempt Entity'' does not 
include any ``financial entity,'' as defined in CEA section 2(h)(7)(C).
    B. Exempt Non-Financial Energy Transaction means any agreement, 
contract, or transaction based upon a ``commodity,'' as such term is 
defined and interpreted by the CEA and regulations there under, so long 
as the primary purpose of the agreement, contract, or transaction is to 
satisfy existing or anticipated contractual obligations to facilitate 
the generation, transmission, and/or delivery of electric energy 
service to customers at the lowest cost possible, and the agreement, 
contract, or transaction is intended for making or taking physical 
delivery of the commodity upon which the agreement, contract, or 
transaction is based. The term ``Exempt Non-Financial Energy 
Transaction'' excludes agreements, contracts, and transactions based 
upon, derived from, or referencing any interest rate, credit, equity or 
currency asset class, or any grade of a metal, agricultural product, 
crude oil or gasoline that is not used as fuel for electric energy 
generation. Exempt Non-Financial Energy Transactions are limited to the 
following categories, which may exist as stand-alone agreements or as 
components of larger agreements that combine only the following 
categories of transactions:
    1. Electric Energy Delivered transactions consist of arrangements 
in which a provider Exempt Entity agrees to deliver a specified amount 
of electric energy to a recipient Exempt Entity within a defined 
geographic service territory, load, or electric system over the course 
of an agreed period of time. Such transactions include ``full 
requirements'' contracts, under which one Exempt Entity becomes 
obligated to provide, and the recipient Exempt Entity becomes obligated 
to take, all of the electric energy the recipient needs to provide 
reliable electric service to its fluctuating electric load over a 
specified delivery period at one or multiple delivery points or 
locations, net of any electric energy the recipient is able to produce 
through generation assets that it owns.
    2. Generation Capacity transactions consist of agreements in which 
a recipient Exempt Entity purchases from a provider Exempt Entity the 
right to call upon a specified amount of the provider Exempt Entity's 
electric energy generation assets to supply electric energy within a 
defined geographic area, regardless of whether such right is ever 
exercised for the purposes of the recipient Exempt Entity meeting its 
location-specific reliability obligations. Such transactions also may 
specify certain conditions that must exist prior to exercising the 
right to use an Exempt Entity's generation assets, or establish an 
agreement between Exempt Entities to share pooled electric generation 
assets in order to satisfy regionally-imposed demand side management 
program requirements.
    3. Transmission Services transactions consist of arrangements in 
which a provider Exempt Entity owning transmission lines sells to a 
recipient Exempt Entity the right to deliver a specified amount of the 
recipient Exempt Entity's electric energy from one designated point on 
the transmission lines to another, at a set price per wattage and over 
a certain time period, in order for the recipient Exempt Entity to 
provide electric energy to its customers. Such transactions may include 
ancillary services related to transmission such as congestion 
management and system losses.

[[Page 51013]]

    4. Fuel Delivered transactions include arrangements used to buy, 
sell, transport, deliver, or store fuel used in the generation of 
electric energy by an Exempt Entity. Additionally, Fuel Delivered 
transactions may include an agreement to manage the operational basis 
or exchange (i.e., location or time of delivery) risk of an Exempt 
Entity that arises from its location-specific, seasonal or otherwise 
variable operational need for fuel to be delivered.
    5. Cross-Commodity Pricing transactions include arrangements such 
as heat rate transactions and tolling agreements in which the price of 
electric energy delivered is based upon the price of the fuel source 
used to generate the electric energy. Cross-Commodity transactions also 
include fuel delivered agreements in which the price paid for fuel used 
to generate electric energy is based upon the amount of electric energy 
produced.
6. Other Goods and Services
    Other Goods and Services transactions consist of arrangements in 
which the Exempt Entities enter into an agreement to share the costs 
and economic benefits related to construction, operation, and 
maintenance of facilities for the purposes of generation, transmission, 
and delivery of electric energy to customers. In a full requirements 
contract between Exempt Entities that share ownership of generation 
assets, the provider Exempt Entity may determine how generation to meet 
the recipient Exempt Entity's full requirements will be allocated among 
the provider's independent generation assets, the jointly-owned 
generation assets, and the recipient's independent generation assets. 
Other Goods and Services transactions also may include agreements 
between Exempt Entities to operate each other's facilities, share 
equipment and employees, and interface on each other's behalf with 
third parties such as suppliers, regulators and reliability 
authorities, and customers, regardless of whether such agreements are 
triggered as contingencies in emergency situations only or are 
applicable during the normal course of operations of an Exempt Entity.
    C. Conditions. The relief provided herein is subject to the 
Commission's general anti-fraud, anti-manipulation and enforcement 
authority under the CEA, including but not limited to CEA sections 
2(a)(1)(B), 4b, 4c(b), 4o, 6(c), 6(d), 6(e), 6c, 6d, 8, 9 and 13, and 
Commission rules 32.4 and Part 180. Additionally, the Commission 
reserves its authority to inspect books and records kept in the normal 
course of business that relate to Exempt Non-Financial Energy 
Transactions between Exempt Entities pursuant to the Commission's 
regulatory inspection authorities. The relief provided herein does not 
affect the jurisdiction of FERC or any other government agency over the 
entities and transactions described herein. Furthermore, the Commission 
reserves the right to revisit any of the terms and conditions of the 
relief provided herein and alter or revoke such terms and conditions as 
necessary in order for the Commission to execute its duties and advance 
the public interests and purposes under the CEA, including a 
determination that certain entities and transactions described herein 
should be subject to the Commission's full jurisdiction.

V. Request for Comment

    The Commission requests comment on all aspects of the issues 
presented by this proposed order. The Commission specifically requests 
comment on the scope of both the (a) transactions and (b) entities 
which would be eligible to rely upon the exemption provided in the 
proposed order. In addition, the Commission requests comment on the 
following questions:
    1. Should the Commission limit the scope of Exempt Entities to only 
those electric utilities described by FPA section 201(f), given that 
Congress limited CEA section 4(c)(6)(C) thereto (or, is it an 
appropriate use of the Commission's general exemptive authority 
pursuant to CEA section 4(c)(1) to exempt the non-FPA 201(f) electric 
cooperatives)? If it is appropriate to expand the scope beyond FPA 
201(f) entities, should the Commission still limit the scope of 
electric cooperatives included as Exempt Entities to only those 
cooperatives with tax exempt status under the IRC (i.e., those that 
receive at least 85 percent of revenue from the cooperative 
membership)?
    2. In light of other exemptive authority that was added to the CEA 
by the Dodd-Frank Act, such as the end-user exception in CEA section 
2(h)(7)(A), is relief pursuant to CEA section 4(c) necessary and/or 
appropriate for Exempt Non-Financial Energy Transactions between Exempt 
Entities as described herein?
    3. Should the Commission require that any Exempt Entity that is 
described by FPA section 201(f) relying on the relief provided herein 
notify the Commission of its change in status under FPA section 201(f) 
as a condition of such relief? If so, what purpose(s) would this serve?
    4. For the purpose of issuing this Proposed Order, the Commission 
concluded that Exempt Non-Financial Energy Transactions do not serve a 
price discovery purpose. Please comment on the Commission's assessment. 
What facts and circumstances would require the Commission to revisit 
its analysis and alter the relief proposed herein such that reporting 
to an SDR should be required for certain transactions? \112\
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    \112\ Commenters should consider what impact, if any, it would 
have on the response to the question posed if FERC finalizes its 
recent proposal to require price transparency reporting in electric 
wholesale markets, even by FPA 201(f) entities. See supra note 100.
---------------------------------------------------------------------------

    5. The Commission believes that the Proposed Order's definition of 
``Exempt Non-Financial Energy Transaction,'' in combination with the 
definition of ``Exempt Entity'', should ensure that Exempt Non-
Financial Energy Transactions cannot be used for speculative purposes. 
Please comment on whether the Proposed Order would so foreclose the 
possibility for speculative trading and, if not, how the Proposed Order 
should be modified to achieve such a goal.
    6. The Commission has proposed that electric facilities owned by 
only federally-recognized Indian tribes be included as Exempt Entities 
for purposes of the relief provided in the Proposed Order. The 
Commission specifically requests comment on every aspect of the 
Proposed Order as it relates to Indian tribes.
    7. The Commission has limited its definition of Exempt Non-
Financial Energy Transaction to six categories. Do any of the 
transactions described by or covered under these categories fail to 
come under the Commission's jurisdiction, such that relief pursuant to 
CEA section 4(c) is unnecessary and/or inappropriate, either due to an 
interpretation in the Products Release or otherwise?
    8. Per the Petition's request, should the Commission stipulate that 
the relief provided in the Proposed Order (i) applies retroactively to 
the enactment of the Dodd-Frank Act and (ii) that transactions covered 
by the relief will not be considered by the Commission for any purpose 
which affects or may affect an Exempt Entity's regulatory status under 
the CEA (e.g., in determining status as a swap dealer or major swap 
participant)?
    9. The Petition requested that the Commission provide categorical 
relief by including ``any other agreement, contract, or transaction to 
which an Exempt Entity is a party.'' Should the Commission provide such 
categorical relief, so long as the primary purpose of

[[Page 51014]]

the agreement, contract, or transaction is to satisfy existing or 
anticipated contractual obligations to facilitate the generation, 
transmission, and/or delivery of electric energy service to customers 
at the lowest cost possible, and the contract is intended to be settled 
through physical delivery of the underlying commodity?
    10. Can any Exempt Non-Financial Energy Transaction, as defined in 
the Proposed Order, or any component of an Exempt Non-Financial Energy 
Transaction, be used to hedge price risk in an underlying commodity? If 
so, should the Commission explicitly exclude such price-hedging 
transactions from the definition of Exempt Non-Financial Energy 
Transaction?

VI. Related Matters

A. Regulatory Flexibility Act
    The Regulatory Flexibility Act (``RFA'') requires that Federal 
agencies consider whether proposed rules will have a significant 
economic impact on a substantial number of small entities and, if so, 
provide a regulatory flexibility analysis on the impact. The relief 
provided in the Proposed Order may be available to some small entities, 
because they may fall within standards established by the Small 
Business Administration (``SBA'') defining entities with electric 
energy output of less than 4,000,000 megawatt hours per year as a 
``small entity.'' \113\
---------------------------------------------------------------------------

    \113\ U.S. Small Business Administration, Table of Small 
Business Size Standards Matched to North American Industry 
Classification System Codes, footnote 1 (effective March 26, 2012), 
available at http://www.sba.gov/sites/default/files/files/Size_Standards_Table.pdf.
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    The Commission has considered carefully the potential effect of 
this Proposed Order on small entities and has determined that the 
proposed order will not have a significant economic impact on any 
Exempt Entity, including any entities that may be small. Rather, the 
Proposed Order relieves the economic impact that the Exempt Entities, 
including any small entities that may opt to take advantage of it, by 
exempting certain of their transactions from the application of 
substantive regulatory compliance requirements of the CEA and 
Commission regulations there under. Significantly, the Proposed Order 
prevents new requirements for swaps, such as clearing, trade execution 
and regulatory reporting, from affecting transactions that Exempt 
Entities traditionally have engaged in to serve their unique public 
service mission of providing reliable, affordable electric energy 
service to customers. Absent such relief and to the extent Exempt Non-
Financial Energy Transactions would qualify as swaps, small entities 
covered by the Proposed Order could be subject to compliance with all 
aspects of the CEA and its implementing regulations. Accordingly, the 
Chairman, on behalf of the Commission, hereby certifies pursuant to 5 
U.S.C. 605(b) that the Proposed Order will not have a significant 
economic impact on a substantial number of small entities.

B. Paperwork Reduction Act

    Under the Paperwork Reduction Act (``PRA''), an agency may not 
conduct or sponsor, and a person is not required to respond to, a 
collection of information unless it displays a currently valid control 
number from the Office of Management and Budget (``OMB''). The Proposed 
Order does not contain any new information collection requirements that 
would require approval of OMB under the PRA.\114\ While the Commission 
reserves its authority to inspect books and records kept in the normal 
course of business that relate to Exempt Non-Financial Energy 
Transactions between Exempt Entities pursuant to the Commission's 
regulatory inspection authorities, the Commission is not imposing a 
recordkeeping burden with respect to the books and records of Exempt 
Non-Financial Energy Transactions that already are kept in the normal 
course of business. Moreover, any inspection of books and records 
typically only will occur in the event that circumstances warrant the 
need to gain greater visibility with respect to Exempt Non-Financial 
Energy Transactions as they relate to Exempt Entities' overall market 
positions and to ensure compliance with the terms of this Proposed 
Order. Accordingly, each inquiry would be specific to the facts 
triggering the inquiry, and thus will not involve ``answers to 
identical questions posed to * * * ten or more persons,'' as the term 
``collection of information'' is defined in the PRA in pertinent 
part.\115\
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    \114\ 44 U.S.C. 3501 et seq.
    \115\ 44 U.S.C. 3502(3)(a)(1). See also 44 U.S.C. 
3518(c)(1)(B)(i) and (ii) (excluding collections of information 
related to administrative investigations against specific 
individuals or entities, and any subsequent civil actions).
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C. Consideration of Costs and Benefits

1. Introduction
    Section 15(a) of the CEA \116\ requires the Commission to consider 
the costs and benefits of its actions before promulgating a regulation 
under the CEA or issuing certain orders. Section 15(a) further 
specifies that the costs and benefits shall be evaluated in light of 
five broad areas of market and public concern: (1) Protection of market 
participants and the public; (2) efficiency, competitiveness and 
financial integrity of futures markets; (3) price discovery; (4) sound 
risk management practices; and (5) other public interest 
considerations. The Commission considers the costs and benefits 
resulting from its discretionary determinations with respect to the 
Section 15(a) factors.
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    \116\ 7 U.S.C. 19(a).
---------------------------------------------------------------------------

    Prior to the passage of the Dodd-Frank Act, swap market activity 
was not regulated. In the wake of the financial crisis of 2008, 
Congress adopted the Dodd-Frank Act, in part, to address conditions 
with respect to swap market activities.\117\ Among other things, the 
Dodd-Frank Act amends the CEA to establish a comprehensive regulatory 
framework for swaps.\118\ In amending the CEA, however, the Dodd-Frank 
Act preserved the Commission's authority under CEA section 4(c)(1) to 
``promote responsible economic or financial innovation and fair 
competition'' by exempting any transaction or class of transactions, 
including swaps, from select provisions of the CEA.\119\ It also added 
new subparagraph 4(c)(6)(C) to the CEA specifically directing the 
Commission, in accordance with 4(c)(1) and (2), to exempt agreements, 
contracts, or transactions entered into between FPA 201(f) entities if 
doing so ``is consistent with the public interest and the purposes of'' 
the CEA.\120\ For reasons explained above,\121\ the Commission proposes 
to exercise its

[[Page 51015]]

authority under CEA section 4(c)(1) and 4(c)(6) with regard to Exempt 
Non-Financial Energy Transactions \122\ engaged in between Exempt 
Entities,\123\ subject to the Commission's general anti-fraud, anti-
manipulation, and enforcement authority pursuant to CEA sections 
2(a)(1)(B), 4b, 4c(b), 4o, 6(c), 6(d), 6(e), 6c, 6d, 8, 9 and 13, and 
Commission rules 32.4 and Part 180. Additionally, the Commission has 
reserved its authority to inspect the books and records of Exempt Non-
Financial Energy Transactions already kept in the normal course of 
business pursuant to the Commission's regulatory inspection 
authorities, in the event that circumstances warrant the need to gain 
greater visibility with respect to Exempt Non-Financial Energy 
Transactions as they relate to Exempt Entities' overall market 
positions and to ensure compliance with the terms of this Proposed 
Order.
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    \117\ As the Financial Crisis Inquiry Commission explained:
    The scale and nature of the [OTC] derivatives market created 
significant systemic risk throughout the financial system and helped 
fuel the panic in the fall of 2008: millions of contracts in this 
opaque and deregulated market created interconnections among a vast 
web of financial institutions through counterparty credit risk, thus 
exposing the system to a contagion of spreading losses and defaults.
    Financial Crisis Inquiry Commission, ``The Financial Crisis 
Inquiry Report: Final Report of the National Commission on the 
Causes of the Financial and Economic Crisis in the United States,'' 
Jan. 2011, at 386, available at http://www.gpo.gov/fdsys/pkg/GPO-FCIC/pdf/GPO-FCIC.pdf
    \118\ See discussion above at note [13]. Dodd-Frank Act section 
721 (amending the CEA to add new section 1a(47)) defines the term 
``swap'' to include ``[an] option of any kind that is for the 
purchase or sale, or based on the value, of 1 or more * * * 
commodities * * *'').
    \119\ Section 4(c)(1) of the CEA.
    \120\ As discussed above in section I.A., CEA sections 4(c)(2) 
and 4(c)(3) further articulate the conditions precedent to granting 
an exemption under 4(c)(1) and 4(c)(6)(C), including that the 
exempted agreements, contracts, or transactions be entered into 
between ``appropriate persons,'' as that term is defined in 
4(c)(6)(3).
    \121\ See section III.B. above.
    \122\ As discussed and further described above in section 
III.A.2., these consist of: any agreement, contract, or transaction 
based upon a ``commodity,'' as such term is defined and interpreted 
by the CEA and regulations there under, so long as the primary 
purpose of the agreement, contract, or transaction is to satisfy 
existing or anticipated contractual obligations to facilitate the 
generation, transmission, and/or delivery of electric energy service 
to customers at the lowest cost possible. When entered into, Exempt 
Non-Financial Energy Transactions shall always be intended for 
making or taking physical delivery of the commodity upon which the 
transaction is based, and such commodity shall never be based upon, 
derived from, or reference any interest rate, credit, equity or 
currency asset class, or any grade of a metal, agricultural product, 
crude oil or gasoline that is not used as fuel for electric 
generation. Exempt Non-Financial Energy Transactions are limited to 
the following categories: electric energy delivered, generation 
capacity, transmission services, fuel delivered, cross-commodity 
pricing, and other goods and services.
    \123\ As discussed and further described above in section 
III.A.1, these are: (i) Any government-owned electric facility 
recognized under Federal Power Act (``FPA'') section 201(f), 16 
U.S.C. 824(f); (ii) any electric facility otherwise subject to 
regulation as a ``public utility'' under the FPA that is owned by an 
Indian tribe recognized by the U.S. government pursuant to section 
104 of the Act of November 2, 1994, 25 U.S.C. 479a-1; (iii) any 
cooperatively-owned electric utility, regardless of status pursuant 
to FPA section 201(f), so long as the utility is treated as a 
``cooperative'' organization under Internal Revenue Code section 
501(c)(12) or 1381(a)(2)(C), 26 U.S.C. 501(c)(12), 1381(a)(2)(C), 
and exists for the primary purpose of providing electric energy 
service to its members at the lowest possible cost; or iv) any not-
for-profit entity that is wholly owned, directly or indirectly, by 
any one or more of the foregoing.
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    In the discussion that follows, the Commission considers the costs 
and benefits of the exemptive order proposed herein (the ``Proposed 
Order'') to the public and market participants generally, and to Exempt 
Entities specifically. As earlier discussed in sections I.A. and 
III.A.2., to exempt transactions under CEA section 4(c), the Commission 
need not first determine--and is not determining--whether the 
transactions subject to the exemption fall within the CEA. However, to 
capture all potential costs and benefits, this consideration assumes 
that the transactions may now or in the future be swaps.\124\ In the 
event the subject transactions would not be subject to the Commission's 
jurisdiction, the costs and benefits of this Proposed Order relative to 
the baseline scenario discussed below would be zero.
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    \124\ Accord note 81, supra.
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2. Baseline
    The Commission considers the costs and benefits of this Proposed 
Order against a baseline scenario of non-action. In other words, the 
proposed baseline is the alternative situation that would result if the 
Commission declines to exercise its exemptive authority under CEA 4(c). 
This means that to the extent Exempt Non-Financial Energy Transactions 
engaged in between Exempt Entities qualify as a transaction subject to 
regulation under the CEA, they are subject to the regulatory regime 
that the CEA, as amended by the Dodd-Frank Act, and Commission 
regulations prescribes.
    Under the post-Dodd-Frank Act regulatory regime for swaps, Exempt 
Entity swap counterparties that, as represented in the Petition, are 
``nonfinancial end-users of [Exempt Non-Financial Energy Transactions 
entered into] only to hedge or mitigate commercial risks'' \125\ are 
subject to the Commission's general anti-fraud, anti-manipulation, and 
enforcement authority,\126\ as well as requirements for swap data 
reporting \127\ and recordkeeping.\128\ CEA section 2(h)(7) (the ``end-
user exception''), excepts a swap from swap clearing \129\ and trade 
execution,\130\ requirements if one counterparty is ``not a financial 
entity; * * * is using swaps to hedge or mitigate commercial risk; and 
* * * notifies the Commission, in a manner set forth by the Commission, 
how it generally meets its financial obligations associated with 
entering into non-cleared swaps.'' However, unless both Exempt Entity 
counterparties are ``eligible contract participants'' (``ECPs''),\131\ 
CEA section 2(e) prohibits them from executing a swap other than on a 
registered DCM, including directly transacting the swap 
bilaterally.\132\ Against this baseline scenario, with respect to an 
Exempt Non-Financial Energy Transaction that is a swap, the public and 
market participants, including Exempt Entities, would experience the 
costs and benefits related to the regulations, noted above, for them as 
swaps. As considered below, the Proposed Order could alter these costs 
and benefits.
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    \125\ Petition at 33.
    \126\ See CEA sections 2(a)(1)(B), 4b, 4c(b), 4o, 6(c), 6(d), 
6(e), 6c, 6d, 8, 9 and 13, and Commission rules 32.4 and Part 180.
    \127\ The CEA as amended by the Dodd-Frank Act contemplates two 
types of reporting to swap data repositories (``SDRs''). First, is 
real-time reporting: For every swap executed, certain transaction 
information, including price and volume, is to be reported to an 
SDR'') ``as soon as technologically practicable.'' CEA section 
2(a)(13)(A) & (C); see also Real-Time Public Reporting of Swap 
Transaction Data, 77 FR 1182 (Jan. 9, 2012) (adopting 17 CFR part 43 
regulations to implement real-time reporting). For swaps executed 
off of a DCM or SEF and for which neither counterparty is a swap 
dealer or major swap participant--as the Commission expects Exempt 
Non-Financial Energy Transactions engaged in between Exempt Entities 
would be--the real-time reporting obligation for the transaction 
falls to one of the counterparties, as agreed between themselves. 17 
CFR Sec.  43.3(a)(3) Second, for each swap, additional information 
beyond that required in real-time reports must be reported to an SDR 
in a ``timely manner as may be prescribed by the Commission.'' CEA 
section 2(a)(13)(G); see also Swap Data Recordkeeping and Reporting 
Requirements 77 FR 2136 (Jan. 13, 2012) (adopting 17 CFR part 45); 
Swap Data Recordkeeping and Reporting Requirements: Pre-enactment 
and Transition Swaps 77 FR 35200 (June 12, 2012) (adopting 17 CFR 
part 46).
    \128\ Swap Data Recordkeeping and Reporting Requirements 77 FR 
2136 (Jan. 13, 2012) (adopting 17 CFR part 45); Swap Data 
Recordkeeping and Reporting Requirements: Pre-enactment and 
Transition Swaps 77 FR 35200 (June 12, 2012) (adopting 17 CFR part 
46).
    \129\ CEA section 2(h)(1)(A)(it ``shall be unlawful for any 
person to engage in a swap unless that person submits such swap for 
clearing * * * if the swap is required to be cleared'').
    \130\ Transactions subject to the clearing requirement of CEA 
section 2(h)(1) must be executed on either a designated contract 
market (``DCM'') or a swap execution facility (``SEF''). CEA section 
2(h)(8).
    \131\ The term is defined in CEA section 1a(18). See also 
Further Definition of ``Swap Dealer,'' ``Security-Based Swap 
Dealer,'' ``Major Swap Participant,'' ``Major Security-Based Swap 
Participant,'' and ``Eligible Contract Participant,'' 77 FR 30596 
(May 23, 2012).
    \132\ CEA section 2(e).
---------------------------------------------------------------------------

    Also, the post-Dodd-Frank Act regulatory regime retains 
requirements applicable to ``contract[s] of sale of a commodity for 
future delivery'' within the meaning of CEA section 4(a) (commonly 
referred to as futures contracts), including that section's exchange-
trading requirement for such contracts. Though the Commission need not 
first determine whether the transactions subject to exemption under CEA 
section 4(c) are futures or swaps, it has defined the boundaries for 
inclusion within the Exempt Non-Financial Energy Transaction category 
in a way that comports with the distinctions between futures contracts 
subject to CEA section 4(a) and non-

[[Page 51016]]

futures transactions.\133\ For this reason, the Commission foresees no 
costs or benefits relative to the baseline attributable to exempting 
Exempt Non-Financial Energy Transactions as proposed from CEA section 
4(a).
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    \133\ See, e.g., Statement of Policy Concerning Swap 
Transactions, 54 Fed. Reg. 30694 (CFTC July 21, 1989). For example, 
the transactions encompassed by this proposed exemption would be 
limited to those that are highly bespoke and thus not suitable for 
exchange trading, executed exclusively bilaterally, off-exchange 
between counterparties, and undertaken with the intent of making or 
taking physical delivery of the commodity upon which the transaction 
is based.
---------------------------------------------------------------------------

    The Commission is also cognizant of the regulatory landscape as it 
existed before the Dodd-Frank Act's enactment. Any Exempt Non-Financial 
Energy Transactions engaged in between Exempt Entities that now would 
qualify as swaps (excluding options) were not regulated prior to Dodd-
Frank. Thus, measured against a pre-Dodd-Frank Act reference point, 
Exempt Entities engaging in such swaps could experience costs 
attributable to the conditions placed upon the Proposed Order. For 
example, Exempt Entities were not subject to the Commission's 
regulatory inspection authorities with respect to swap transaction 
records prior to the enactment and effectiveness of the Dodd-Frank Act.
    As a general matter, in its cost-benefit considerations, where 
reasonably feasible, the Commission endeavors to estimate quantifiable 
dollar costs. The costs and benefits of the Proposed Order, however, 
are not presently susceptible to meaningful quantification. 
Accordingly, the Commission discusses proposed costs and benefits in 
qualitative terms.
3. Costs
To Exempt Entities
    The proposed rule is exemptive and would provide Exempt Entities 
with relief from regulatory requirements of the CEA for the narrow 
category of Exempt Non-Financial Energy Transactions engaged in between 
them. As with any exemptive rule or order, the proposed rule is 
permissive, meaning that potentially eligible affiliates are not 
required to elect it. Accordingly, the Commission assumes that an 
entity would rely on the Proposed Order only if the anticipated 
benefits warrant the costs. Here, the Proposed Order provides for the 
continued application of the anti-fraud, anti-manipulation, and 
enforcement provisions of the CEA and its implementing regulations, and 
additionally reserves the Commission inspection authority for books and 
records that the Exempt Entities currently prepare and retain \134\--
all continuations of the baseline regulatory scheme established in the 
CEA. Accordingly, they generate no incremental costs.
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    \134\ For example, Exempt Entities that receive financing from 
the Rural Utilities Service (``RUS'') are required to keep records 
of all master agreements and term contracts for the procurement of 
goods and services. See 18 CFR 125.3 (Schedule of records and 
periods of retention); RUS Bulletin 180-2. Under the books and 
records inspection authority contained in the Proposed Order, the 
Commission could request any of these procurement agreements that 
document an Exempt Non-Financial Energy Transaction for the purchase 
or sale of ``electric energy delivered,'' as such term is defined in 
the Proposed Order.
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To Market Participants and the Public
    The Commission has considered whether an exemption from the CEA as 
proposed for Exempt Non-Financial Energy Transactions engaged in 
between Exempt Entities will expose market participants and the public 
to the risks that the CEA guards against--a potential cost. For a 
variety of reasons, the Commission believes that it does not. These 
reasons include the following:
     The highly bespoke nature of Exempt Non-Financial Energy 
Transactions, as well as the fact that they are used to manage unique 
electricity industry operational risks, rather than price risk of an 
underlying commodity, make them ill-suited for exchange trading and/or 
to serve a useful price discovery function.\135\
---------------------------------------------------------------------------

    \135\ As explained in section III.B.3.d, above, the commercial 
risks that Exempt Non-Financial Energy Transactions face generally 
are not related to fluctuations in the price of a commodity, but are 
rather related to electricity retail demand fluctuations. Exempt 
Entities engage in Exempt Non-Financial Energy Transactions 
primarily to assure their ability to meet production, transmission, 
and/or distribution obligations, not to hedge against the risk of 
electricity prices rising or falling.
---------------------------------------------------------------------------

     The incentive structure for Exempt Entities--as limited to 
not-for-profit governmental, tribal, and IRC section 501(c)(12) or 
section 1381(a)(2)(c) electric cooperative entities--is substantially 
different than that of investor-owned entities and poses a low risk for 
fraud, manipulation, or other abusive practices.\136\
---------------------------------------------------------------------------

    \136\ See section II.A.1. above.
---------------------------------------------------------------------------

     Exempt Non-Financial Energy Transactions are executed 
bilaterally within a closed-loop of non-financial, not-for-profit 
electric utility entities, are not market facing, and therefore have 
little, if any, ability to materially impact liquidity, fairness or 
financial security of derivative product trading on DCMs or SEFs.\137\
---------------------------------------------------------------------------

    \137\ See section III.B.3.a. above.
---------------------------------------------------------------------------

     This closed-loop trading characteristic, combined with the 
nonfinancial nature of the transacting parties, also limits the ability 
of Exempt Non-Financial Energy Transactions to create systemic 
risk.\138\
---------------------------------------------------------------------------

    \138\ See section III.B.3.b. above.
---------------------------------------------------------------------------

    Moreover, besides carefully defining the boundaries for Exempt Non-
Financial Energy Transactions between Exempt Entities, the Commission's 
Proposed Order incorporates conditions designed to protect the markets 
subject to the Commission's jurisdiction. Specifically, the Commission 
proposes to retain the general anti-fraud, anti-manipulation, and 
enforcement authority contained in the CEA and its implementing 
regulations. Additionally, the Commission is also retaining authority 
to inspect books and records, pursuant to its regulatory inspection 
authorities, in the event that circumstances warrant the need to gain 
greater visibility with respect to Exempt Non-Financial Energy 
Transactions as they relate to Exempt Entities' overall market 
positions and compliance with this Proposed Order. Accordingly, based 
on the expectations that--for the narrow subset of electric industry 
transactions covered by this Proposed Order--the risk potential, at 
most, is remote and the prescribed conditions appropriate to contain 
them to the extent they may emerge, the Commission foresees no material 
costs attributable to risk associated with the Proposed Order.
    The Commission has also considered the potential for the Proposed 
Order to exact a competitive cost by affording Exempt Entities an 
advantage vis-[agrave]-vis other market participants that may not be 
entitled to the exemption. As not-for-profit governmental, tribal, and 
cooperative entities as defined in the Proposed Order, the Commission 
understands that the mandate for Exempt Entities is to provide 
reliable, affordable electricity for their customers. While the 
Proposed Order will afford Exempt Entities flexibility and/or reduced 
compliance burden to manage their operational risks relative to non-
Exempt Entities, the Commission has no basis to expect that in so doing 
the Proposed Order will impose a competitive cost on the markets 
subject to its jurisdiction.
4. Benefits
To Exempt Entities
    Measured against the baseline scenario, the Proposed Order 
expectedly will benefit Exempt Entities by lessening the likelihood 
that CEA compliance would diminish their ability and/or incentive to 
continue to engage in Exempt Non-Financial Energy Transactions that, as 
described in the

[[Page 51017]]

Petition and above,\139\ are an operational tool relied upon by Exempt 
Entities to effectively execute their public service mission. It will 
also benefit them by avoiding regulatory costs to comply with CEA swap 
requirements whether or not any Exempt Non-Financial Energy Transaction 
actually constitutes a swap.\140\
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    \139\ Petition at 12 (transactions for which exemption requested 
``are intrinsically related to the needs of * * * the [not-for-
profit] Electric Entities * * * which arise from their respective 
electric facilities and ongoing electric operations and public 
service obligations'' (citation omitted)); section III.A.2, above 
(the proposed order defines Exempt Non-Financial Energy Transactions 
as any agreement, contract, or transaction entered into primarily 
``to satisfy existing or anticipated contractual obligations to 
facilitate the generation, transmission, and/or delivery of electric 
energy service to customers at the lowest cost possible * * * .'').
    \140\ As discussed below with respect to benefits to market 
participants and the public, Exempt Entities' members and other 
customers should be the indirect beneficiaries of these avoided 
costs.
---------------------------------------------------------------------------

    To the extent any Exempt Non-Financial Energy Transactions are 
swaps, as a threshold matter Exempt Entities could not execute them off 
of a registered DCM unless both Exempt-Entity counterparties qualify as 
ECPs.\141\ The relevant criteria for determining ECP status varies for 
Exempt Entities that are governmental entities (or political 
subdivisions of governmental entities) and those that are not. For the 
former, governmental Exempt Entities must meet certain line of business 
requirements,\142\ or ``own * * * and invest * * * on a discretionary 
basis $50,000,000 or more in investments.\143\ For the latter, non-
governmental Exempt Entities either must have: (a) Assets exceeding 
$10,000,000; (b) a guarantee for obligations; or, (c) greater than 
$1,000,000 net worth and ``enter * * * into an agreement, contract, or 
transaction in connection with the conduct of the entity's business or 
to manage the risk associated with an asset or liability owned or 
incurred or reasonably likely to be owned or incurred by the entity in 
the conduct of the entity's business.'' \144\ While some of the larger 
Exempt Entities in particular may meet the definitional requirements to 
be ECPs, the Petition does not provide information evidencing that all 
Exempt Entities for all types of Exempt Non-Financial Energy 
Transaction clearly would.\145\
---------------------------------------------------------------------------

    \141\ CEA section 2(e).
    \142\ That is, have ``a demonstrable ability, directly or 
through separate contractual arrangements, to make or take delivery 
of the underlying commodity [or] incur * * * risks, in addition to 
price risk, related to the commodity.'' CEA section 1a(17)(A)(i) & 
(2) (as referenced in CEA section 1a(18)(A)(vii)(aa)). CEA section 
1a(18)(A)(vii) specifies alternative criteria to qualify for 
governmental-entity ECP status that do not appear relevant given 
that Exempt Entities are not SDs, MSPs, or financial entities.
    \143\ CEA section 1a(18)(A)(vii)(bb).
    \144\ CEA section 1a(18)(A)(v).
    \145\ Furthermore, a comment letter submitted by two of the 
Petitioners in connection with the Commission rulemaking on the 
Further Definition of ``Swap Dealer,'' ``Security-Based Swap 
Dealer,'' ``Major Swap Participant,'' ``Major Security-Based Swap 
Participant,'' and ``Eligible Contract Participant,'' states that 
some not-for-profit consumer-owned electric utilities ``may not meet 
the financial tests listed in the definition of ECP due to the 
relatively small size of their physical assets.'' Letter from NRECA, 
APPA and LPPC dated February 22, 2011, RIN 3235-AK65, at 12.
---------------------------------------------------------------------------

    If Exempt Entities are not ECPs, and given that Exempt Non-
Financial Energy Transactions, as proposed, are bespoke to an extent 
that makes them incapable of exchange trading, absent Commission action 
non-ECP Exempt Entities would be unable to engage bilaterally in any 
Exempt Non-Financial Energy Transactions that are swaps. Relative to a 
circumstance that would preclude non-ECP Exempt Entities from 
continuing to engage in Exempt Non-Financial Energy Transactions that 
are swaps, the Proposed Order would afford the benefit of allowing the 
use of transactions that are closely related to Exempt Entities' public 
service mission to provide affordable, reliable electricity. The 
Proposed Order would also save Exempt Entities the time and expense 
that would be necessitated to determine if they were ECPs. For, with 
the Proposed Order, ECP status becomes largely irrelevant, while 
without it, Exempt Entities may have to concern themselves with ECP 
status determinations as a threshold for engaging in certain 
transactions.
    The Proposed Order would also avoid potential costs that Exempt 
Entities might incur to comply with swap data reporting and 
recordkeeping requirements as articulated in Commission regulations for 
any Exempt Non-Financial Energy Transactions that were swaps.\146\
---------------------------------------------------------------------------

    \146\ See Real-Time Public Reporting of Swap Transaction Data, 
77 FR 1182, 1232-40 (Jan. 9, 2012) (adopting 17 CFR part 43 
regulations to implement real-time reporting). Swap Data 
Recordkeeping and Reporting Requirements 77 FR 2136, 2176-93 (Jan. 
13, 2012) (adopting 17 CFR part 45); Swap Data Recordkeeping and 
Reporting Requirements: Pre-enactment and Transition Swaps 77 FR 
35200, 35217-25 (June 12, 2012) (adopting 17 CFR part 46).
    Swap Data Recordkeeping and Reporting Requirements 77 FR 2136 
(Jan. 13, 2012) (adopting 17 CFR part 45); Swap Data Recordkeeping 
and Reporting Requirements: Pre-enactment and Transition Swaps 77 FR 
35200 (June 12, 2012) (adopting 17 CFR part 46).
---------------------------------------------------------------------------

    Even for Exempt Non-Financial Energy Transactions ultimately 
determined not to be swaps, if Exempt Entities perceived some potential 
that they could be swaps (now or as evolved in the future), Exempt 
Entities would likely need to expend resources to monitor contemplated 
transactions and make status determinations as to them. Moreover, the 
bespoke nature of these transactions could complicate the ability to 
generalize conclusions across transactions, potentially resulting in a 
need for more frequent, individualized assessments that could multiply 
determination costs. While the Commission lacks a basis to meaningfully 
project any such benefit in dollar terms, qualitatively it expects that 
the benefit would include the avoided costs of training staff to 
differentiate between swap and non-swap transactions and, in some cases 
at least, to obtain an expert legal opinion to support a determination. 
Additionally, uncertainty about whether a certain transaction would or 
would not be deemed a swap could prompt an Exempt Entity to forego a 
beneficial transaction or to substitute a transaction that served the 
operational needs less effectively. Avoiding a result that would 
diminish the use of operationally-efficient Exempt Non-Financial Energy 
Transactions is another benefit.
    To Market Participants and the Public
    For reasons similar to those discussed above in the Commission's 
analysis of the Proposed Order under CEA sections 4(c)(1) and (6), the 
Commission expects that this Proposed Order will benefit the public 
generally.\147\
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    \147\ In that the impacted transactions are undertaken 
exclusively in a closed-loop environment from which financial 
participants are absent, the Commission does not foresee that 
derivative market participants beyond Exempt Entities will realize 
either a cost (as earlier discussed) or benefit impact.
---------------------------------------------------------------------------

    First, the Commission believes that the Proposed Order aligns with 
the beneficial public interests served by the FPA, which--in addition 
to granting comprehensive jurisdiction over the electric industry to 
FERC--reflects, through FPA section 201(f)'s exemption, Congress' 
implicit view that, with respect to certain activities, a regulatory 
light-touch and avoidance of overlapping regulatory regimes for 
governmental and small cooperative electric utilities serves the 
public-interest objectives of the FPA.\148\ The

[[Page 51018]]

Commission interprets CEA section 4(c)(6)(C), directing the Commission 
to provide an exemption for FPA 201(f) entities to the extent 
consistent with the public interest and the CEA, as an extension of 
that view. Accordingly, by tailoring the Proposed Order for FPA section 
201(f) entities (as well as others deemed equally suitable) in a 
careful manner intended to preserve the public interests protected 
under the CEA, the Proposed Order accommodates the public interests of 
both statutes.
---------------------------------------------------------------------------

    \148\ See Salt River Project Agricultural Improvement and Power 
District v. Federal Power Commission, 391 F. 2d 470, 475 (D.C. Cir. 
1968) (``But of the 19 major abuses summarized [in a Federal Trade 
Commission report to Congress on the electric utility industry], 
virtually none could be associated with the cooperative structure 
where ownership and control is vested in the consumer-owners* * * 
Consequently, the attention of the 74th Congress, in enacting the 
Federal Power Act, was focused on the sorts of evils associated 
exclusively with investor-owned utilities'') In Salt River, the 
court considered whether the FPA 201(f) exemption, which at the time 
did not expressly encompass REA-financed cooperatives--entities 
subject to ``extensive [REA] supervision over the planning, 
construction and operation of the facilities [REA] finances''--fell 
within the exemption, as the FPC had interpreted that it did. Id. at 
473. The court found that, among other factors, the Congressional 
inaction in the face of 30 years of administrative practice 
extending FPA 201(f) exemptive treatment to REA-financed 
cooperatives reinforced the FPC's interpretation that REA-financed 
cooperatives were exempt from FPA coverage as instrumentalities of 
the Government under Section 201(f). Id. at 476.
---------------------------------------------------------------------------

    Second, in that the proposed Exempt Entities share the same public-
service mission of providing affordable, reliable electricity to their 
customers, those aspects of the Proposed Order that benefit Exempt 
Entities directly should indirectly benefit their customers as well. 
For example, the Proposed Order would enable non-ECP Exempt Entities to 
engage in swap Exempt Non-Financial Energy Transactions that would be 
barred to them under CEA section 2(e), or facilitate the likelihood 
that they would continue to engage in Exempt Non-Financial Energy 
Transactions that they might choose to forego for regulatory 
uncertainty or costs reasons absent the exemption. In these 
circumstances, Exempt Entity customers should be the ultimate 
beneficiaries (via supply reliability and affordability) of the 
operational risk-management and efficiencies that Exempt Non-Financial 
Energy Transactions afford. Similarly, to the extent that the Proposed 
Order enables Exempt Entities to avoid compliance and/or monitoring 
costs they would otherwise incur, the non-profit structure, compliance 
with requisite Internal Revenue Code conditions, and public service 
mission that Exempt Entities share means that the cost savings should 
be passed through to members and other customers proportionately in the 
form of lower electricity prices and/or higher revenue distributions to 
members.
    And third, the public also benefits by the promotion of economic 
and financial innovation that, as explained above,\149\ the Commission 
expects this Proposed Order will further. For, the unique environment 
in which these electric utilities must operate to reliably serve their 
customer load in the face of constantly fluctuating demand--compounded 
by the fact that many of these Exempt Entities do not enjoy the same 
scale economies as investor-owned utilities--places a premium on 
innovative solutions to operational issues. Exempt Non-Financial Energy 
Transactions represent one such innovation. The Commission envisions 
the Proposed Order, as contemplated by Congress,\150\ will provide 
Exempt Entities regulatory certainty important to their ability to 
continue to utilize and develop innovative solutions through the use of 
highly bespoke, physically settled agreements, contracts, and 
transactions. Accordingly, the Commission expects the Proposed Order to 
benefit the public.
---------------------------------------------------------------------------

    \150\ See HOUSE CONF. REPORT NO. 102-978, 1992 U.S.C.C.A.N. 
3179, 3213 (``4(c) Conf. Report''), noted in section I.A. above.
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5. Costs and Benefits as Compared to Alternatives
    The chief alternatives to this Proposed Order are for the 
Commission to: (1) Decline to exercise its exemptive authority, or (2) 
to exercise its exemptive authority more broadly and without conditions 
as requested in the Petition.
    With respect to the first alternative--decline to exempt--the costs 
and benefit consideration is the mirror-image of that discussed above 
relative to the baseline scenario. A decision not to exercise exemptive 
authority in this circumstance would preserve the current post-Dodd-
Frank regulatory environment.
    Relative to the second alternative of exercising its exemptive 
authority more broadly and in a manner that would provide categorical 
relief from all of the requirements of the CEA as requested in the 
Petition, the Commission has purposefully proposed to define the 
categories of exempt entities and transactions more narrowly, and to 
preserve certain aspects of CEA jurisdiction for them. A potentially 
material difference between the entities that the Petition sought to 
exempt and how the Commission proposes to define the term Exempt 
Entities is the Commission's explicit requirement that an Exempt Entity 
not be a ``financial entity'' within the meaning of CEA section 
2(h)(7)(C). Given, however, that the Petition expressly represents that 
the not-for-profit electric entities that would be encompassed by the 
requested exemption ``are all nonfinancial end users,'' \151\ the 
Commission does not foresee a material cost of expressly stating this 
requirement relative to the Petitioned-for alternative. Conversely, the 
requirement delineates what the Commission considers an important 
gating principle for the exemption's appropriateness, and stating it 
explicitly reduces ambiguity that could fuel future disputes over the 
issue--a benefit.
---------------------------------------------------------------------------

    \151\ Petition at 33.
---------------------------------------------------------------------------

    Also, compared to the Petition's description of transactions for 
which exemption was sought, the proposed definition of Exempt Non-
Financial Energy Transactions incorporates limiting language \152\ and 
articulates additional definitional elements (e.g., intent at execution 
to make or take physical delivery of the commodity upon which the 
transaction is based). The more open-ended, Petitioned-for transaction 
description theoretically could save Exempt Entities effort that they 
might otherwise need to expend to determine whether a transaction 
engaged in between them is or is not exempted compared to the more 
refined and limited definition of Exempt Non-Financial Energy 
Transactions that the Commission proposes. That said, an equally, if 
not more, persuasive case might be made that the greater certitude that 
the proposed definition's more bounded approach provides should 
mitigate determination costs. More importantly, given the inability to 
foresee how these transactions may develop, the Commission considers it 
prudent and in the public interest to ring-fence the definition within 
stated parameters to restrict the potential for the transactions to 
evolve in a manner incompatible with the purposes of the CEA.
---------------------------------------------------------------------------

    \152\ It explicitly limits covered transactions to six 
articulated categories, while the Petition proposed a more open-
ended approach that would have included all transactions relating to 
particular categories, but not others. See Petition at 4-5.
---------------------------------------------------------------------------

    Finally, as proposed, the exemption retains the Commission's 
general anti-fraud, anti-manipulation, and enforcement authority, as 
well as the Commission's authority to review books and records already 
kept in the ordinary course of business in the event that circumstances 
warrant the need to gain greater visibility with respect to Exempt Non-
Financial Energy Transactions as they relate to Exempt Entities' 
overall market positions and to ensure compliance with the terms of 
this Proposed Order, in contrast to the Petition's request for a 
wholesale exemption from the CEA. The Commission believes that the 
first two conditions serve important beneficial ends to ensure the 
integrity of commodity and commodity derivatives markets within its 
jurisdiction. To the

[[Page 51019]]

extent Exempt Entities incur some cost to remain compliant with the 
CEA's anti-fraud, anti-manipulation, and enforcement regime, the 
Commission considers such costs warranted by the importance of 
maintaining commodity market and price discovery integrity. The 
Commission also believes that authority to inspect books and records 
kept in the ordinary course of business, pursuant to its regulatory 
inspection authority, as they relate to Exempt Non-Financial Energy 
Transactions is important to assure visibility into activity in such 
transactions on an as-needed basis. Further, as a general matter, the 
Commission expects infrequently to exert its regulatory inspection 
authority with respect to Exempt Non-Financial Energy Transactions and, 
as proposed, such authority would involve only records that Exempt 
Entities keep in the ordinary course of business, only in the event 
that circumstances warrant the need to gain greater visibility with 
respect to Exempt Non-Financial Energy Transactions as they relate to 
Exempt Entities' overall market positions, and only to ensure 
compliance with the terms of this Proposed Order. The Commission 
anticipates that any costs occasioned by this condition are relatively 
insignificant.
6. Consideration of CEA Section 15(a) Factors
a. Protection of Market Participants and the Public
    As explained above, the Commission does not foresee that the 
Proposed Order will have any effect on the protection of market 
participants and the public. More specifically, Exempt Non-Financial 
Energy Transactions as transacted bilaterally and in a closed loop 
between Exempt Entities in the highly specialized and unique electric-
industry circumstances proposed for exemption do not appear to the 
Commission to generate risks of the nature addressed by the CEA. The 
Commission has attempted to delineate the definitional boundaries for 
Exempt Entities and Exempt Non-Financial Energy Transactions in a 
manner that appropriately ring-fences against the possibility that they 
could generating such risks, either now or as they may evolve in the 
future. Moreover, the exemption incorporates conditions to counter 
residual risk that conceivably, though unexpectedly, might survive 
notwithstanding the Proposed Order's careful definitional crafting.
b. Efficiency, Competitiveness, and Financial Integrity of Futures 
Markets
    The Commission foresees no negative impact from the Proposed Order 
on the efficiency, competitiveness, and financial integrity of markets 
regulated under the CEA. As narrowly limited to highly bespoke 
transactions, executed bilaterally between non-financial entities 
primarily in order to satisfy existing or expected operations-related 
contractual obligations, as opposed to speculating or hedging against 
the price risk of an underlying commodity, the Commission foresees 
little to no capability for Exempt Non-Financial Energy Transactions, 
to the extent any are swaps, to directly impact swap market efficiency, 
competitiveness, or financial integrity. Also, the Proposed Order 
incorporates definitional attributes that largely eliminate the 
potential for any futures market impact.
    Further, as an exercise of the Commission's CEA section 4(c) 
authority to provide legal certain for novel instruments as Congress 
intended, the Proposed Order affords Exempt Entities transactional 
flexibility that the Commission understands to be valuable to their 
ability to efficiently deploy their limited resources.
c. Price Discovery
    The Commission does not foresee that the Proposed Order will 
directly impact price discovery. As discussed above, the highly bespoke 
nature of Exempt Non-Financial Energy Transactions, as well as the fact 
that they are used to manage unique electric industry operational risks 
rather than price risk of an underlying commodity, appears to make them 
ill-suited for exchange trading and/or to serve a useful price 
discovery function.
d. Sound Risk Management Practices
    The Commission expects that the Proposed Order will promote the 
ability of Exempt Entities to manage the operational risks posed by 
unique electric market characteristics, including the non-storable 
nature of electricity and demand that can and frequently does fluctuate 
dramatically within a short time-span. As discussed above, the 
Commission understands that Exempt Non-Financial Energy Transactions 
are an important tool facilitating the ability of Exempt Entities to 
efficiently manage operational risk in fulfillment of their public 
service mission to provide affordable, reliable electricity.
    Also, the Commission does not anticipate that the Proposed Order 
will compromise systemic risk management. The transactions proposed for 
exemption are not market facing, but are executed exclusively within 
closed-loops that do not include financial entities. These 
characteristics, among others, limit the ability of Exempt Non-
Financial Energy Transactions to create systemic risk.
e. Other Public Interest Considerations
    In utilizing its section 4(c)(1) and (6)(C) exemptive authority as 
proposed herein, the Commission believes it is acting to promote the 
broader public interest in an affordable, reliable electric supply as 
Congress contemplated.
7. Request for Public Comment on Costs and Benefits
    The Commission invites public comment on its cost-benefit 
considerations, including the consideration of reasonable alternatives.
    The Commission invites public comment on the magnitude of specific 
costs and benefits that would result from the Proposed Order, including 
data or other information to estimate the dollar value of such costs 
and benefits.
    The Commission invites public comment on any cost or benefit 
impact, direct or indirect, that the Proposed Order may have with 
respect to the factors the Commission considers under CEA section 
15(a), specifically: (a) Protection of market participants and the 
public; (b) efficiency, competitiveness and financial integrity of the 
markets subject to the Commission's jurisdiction; (c) price discovery; 
(d) sound risk management; and (e) other public interest 
considerations.

    Issued in Washington, DC, on August 16, 2012 by the Commission.
Sauntia S. Warfield,
Assistant Secretary of the Commission.

Appendices to Request for comment on a proposal to exempt, pursuant to 
authority in section 4(c) of the Commodity Exchange Act, certain 
transactions between entities described in section 201(f) of the 
Federal Power Act, and other electric cooperatives --Commission Voting 
Summary and Statements of Commissioners

    Note: The following appendices will not appear in the Code of 
Federal Regulations

Appendix 1--Commission Voting Summary

    On this matter, Chairman Gensler and Commissioners Sommers, 
Chilton, O'Malia and Wetjen voted in the affirmative; no 
Commissioner voted in the negative.

[[Page 51020]]

Appendix 2--Statement of Chairman Gary Gensler

    I support the proposed relief from the Dodd-Frank Wall Street 
Reform and Consumer Protection Act (Dodd-Frank Act) swaps provisions 
for certain electricity and electricity-related energy transactions 
between rural electric cooperatives; state, municipal, and tribal 
power authorities; and federal power authorities.
    Congress directed the CFTC, when it is in the public interest, 
to provide relief from the Dodd-Frank Act's swaps market reform 
provisions for certain transactions between these entities.
    For decades, these entities have been recognized as performing a 
public service mission, a fundamentally different function than 
investor-owned utilities. The purpose of these entities is to 
provide their customers or cooperative members with reliable 
electric energy at the lowest cost possible. They have been largely 
exempt from regulation by the Federal Energy Regulatory Commission 
because of their government entity status or their not-for-profit 
cooperative status.
    The scope of the proposed relief extends only to non-financial 
electricity and electricity-related energy transactions for the 
generation, transmission and delivery of electric energy to 
customers. Such transactions must be intended for making or taking 
physical delivery of the underlying commodity.
    I look forward to receiving public comment on the proposed 
relief.

[FR Doc. 2012-20589 Filed 8-22-12; 8:45 am]
BILLING CODE 6351-01-P
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