Court Opinion

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Date Created: 2011-02-05 02:46:31+00
Date Added: 2024-06-11T09:44:37.664578
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       United States Court of Appeals
                  FOR THE DISTRICT OF COLUMBIA CIRCUIT

Argued April 23, 2004                            Decided July 16, 2004

                               No. 02-1121

            MIDWEST ISO TRANSMISSION OWNERS, ET AL.,
                         PETITIONERS

                                     v.

            FEDERAL ENERGY REGULATORY COMMISSION,
                        RESPONDENT

                PUBLIC SERVICE COMMISSION OF THE
                COMMONWEALTH OF KENTUCKY, ET AL.,
                          INTERVENORS

                          Consolidated with
                       02-1122, 03-1236, 03-1256

             On Petitions for Review of Orders of the
             Federal Energy Regulatory Commission

  Paul M. Flynn argued the cause for petitioners Midwest
ISO Transmission Owners, et al. John E. McCaffrey argued
 Bills of costs must be filed within 14 days after entry of judgment.
The court looks with disfavor upon motions to file bills of costs out
of time.
                               2

the cause for Public Service Commission of the Common-
wealth of Kentucky, et al. With them on the briefs were
David W. D’Alessandro, Michael E. Small, and Robert H.
Benna. Jeffrey G. DiSciullo and Linda S. Portasik entered
appearances.
  Robert H. Solomon, Deputy Solicitor, Federal Energy Reg-
ulatory Commission, argued the cause for respondent. With
him on the brief were Cynthia A. Marlette, General Counsel,
and Dennis Lane, Solicitor. Larry D. Gasteiger, Attorney,
entered an appearance.
  Stephen L. Teichler argued the cause for intervenors Mid-
west Independent Transmission System Operator, Inc., et al.
With him on the brief were Stephen G. Kozey, David Martin
Connelly, Jeffrey L. Landsman, Christine C. Ryan, A. Hewitt
Rose, III, Gary D. Bachman, Evan Charles Reese, III,
William F. Fields, Sandra L. Hall, Susan Stevens Miller,
David W. D’Alessandro, John E. McCaffrey, Robert Campbell
McDiarmid, Larissa A. Shamraj, Denise C. Goulet, and
David J. Lynch. Richard G. Raff entered an appearance.

  Before: GINSBURG, Chief Judge, and SENTELLE and ROBERTS,
Circuit Judges.
  Opinion for the Court filed by Circuit Judge ROBERTS.
  ROBERTS, Circuit Judge:
                               I.
    1. In the bad old days, utilities were vertically integrated
monopolies; electricity generation, transmission, and distribu-
tion for a particular geographic area were generally provided
by and under the control of a single regulated utility. Sales
of those services were ‘‘bundled,’’ meaning consumers paid a
single price for generation, transmission, and distribution.
As the Supreme Court observed, with blithe understatement,
‘‘[c]ompetition among utilities was not prevalent.’’ New York
v. FERC, 535 U.S. 1, 5 (2002).
                                3

   In its pathmarking Order No. 888, FERC required utilities
that owned transmission facilities to guarantee all market
participants non-discriminatory access to those facilities. See
Promoting Wholesale Competition Through Open Access
Non-Discriminatory Transmission Services by Public Utili-
ties, FERC Stats. & Regs. ¶ 31,036, 31,635–36 (1996) (Order
No. 888). That is, FERC required all transmission-owning
utilities to provide transmission service for electricity gener-
ated by others on the same basis that they provided transmis-
sion service for the electricity they themselves generated. To
effectuate this introduction of competition, FERC required
public utilities to ‘‘functionally unbundle’’ their wholesale gen-
eration and transmission services by stating separate rates
for each service in a single tariff and offering transmission
service under that tariff on an open-access, non-
discriminatory basis. See New York, 535 U.S. at 11; see
generally California Indep. Sys. Operator Corp. v. FERC,
No. 02-1287, slip op. at 2-4 (D.C. Cir. June 22, 2004).
   As the next step toward the goal of a more competitive
electricity marketplace, Order No. 888 encouraged — but did
not require — the development of multi-utility regional trans-
mission organizations (RTOs). The concern was that the
segmentation of the transmission grid among different utili-
ties, even if each had functionally unbundled transmission,
contributed to inefficiencies that impeded free competition in
the market for electric power. Combining the different seg-
ments and placing control of the grid in one entity — an
RTO — was expected to overcome these inefficiencies and
promote competition. Order No. 888 at 31,730–32; see also
Public Util. Dist. No. 1 of Snohomish County v. FERC, 272
F.3d 607, 610–11 (D.C. Cir. 2001). Better still if the RTO
were run by an independent system operator — an ISO. As
envisioned by FERC, an ISO would assume operational con-
trol — but not ownership — of the transmission facilities
owned by its member utilities, thereby ‘‘separat[ing] opera-
tion of the transmission grid and access to it from economic
interests in generation.’’ Order No. 888 at 31,654; see also
                              4

id. at 31,730–32. The ISO would then provide open access to
the regional transmission system to all electricity generators
at rates established in ‘‘a single, unbundled, grid-wide tariff
that applies to all eligible users in a non-discriminatory
manner.’’ Id. at 31,731; see also California Indep. Sys.
Operator Corp., slip op. at 3–4. FERC called this type of
separation of generation and transmission ‘‘operational un-
bundling,’’ a step beyond ‘‘functional unbundling.’’ Order No.
888 at 31,654. Although several parties to the 1996 rulemak-
ing had requested that FERC require ‘‘operational unbun-
dling’’ or even divestiture of transmission assets, it was
FERC’s considered judgment that ‘‘the less intrusive func-
tional unbundling approach TTT is all that we must require at
this time.’’ Id. at 31,655.
   By 1999, FERC had come to a less sanguine view of the
curative powers of functional unbundling. In FERC’s view,
inefficiencies in the transmission grid and lingering opportu-
nities for transmission owners to discriminate in their own
favor remained obstacles to robust competition in the whole-
sale electricity market. FERC concluded that these prob-
lems could be remedied through the establishment of RTOs,
explaining that ‘‘better regional coordination in areas such as
maintenance of transmission and generation systems and
transmission planning and operation’’ was necessary to ad-
dress regional reliability concerns and to foster regional
competition. See Regional Transmission Organizations, Or-
der No. 2000, FERC Stats. & Regs. ¶ 31,089, 30,999 (1999)
(Order No. 2000) (codified at 18 C.F.R. § 35.34) (citing Staff
Report to FERC on the Causes of Wholesale Electric Pricing
Abnormalities in the Midwest During June 1998, at 5–8 (Sept.
22, 1998)). FERC concluded that RTOs would: ‘‘(1) improve
efficiencies in transmission grid management; (2) impose grid
reliability; (3) remove remaining opportunities for discrimina-
tory transmission practices; (4) improve market performance;
and (5) facilitate lighter handed regulation.’’ Order No. 2000
at 30,993; Public Util. Dist. No. 1, 272 F.3d at 611. To
further encourage RTO development, FERC directed trans-
mission-owning utilities either to participate in an RTO or to
explain their refusal to do so. Public Util. Dist. No. 1, 272
5
F.3d at 612. Importantly, though, Order No. 2000 still did
not require utilities to join RTOs; participation remained
voluntary. See id. at 616.
   For those utilities opting to join an RTO, Order No. 2000
retained a flexible approach, allowing the RTOs to employ a
variety of ownership and operational structures, so long as
the RTO established that it had certain required characteris-
tics and functional capabilities. Id. at 611. FERC required,
inter alia, that an RTO be regional in scope, 18 C.F.R.
§ 35.34(j)(2); ‘‘have operational authority for all transmission
facilities under its control,’’ id. § 35.34(j)(3); ‘‘be the only
provider of transmission service over the facilities under its
control,’’ id. § 35.34(k)(1)(i); and ‘‘have the sole authority to
receive, evaluate, and approve or deny all requests for trans-
mission service,’’ id. Thus, whatever its structure, once a
utility made the decision to surrender operational control of
its transmission facilities to an RTO, any transmissions across
those facilities were subject to the control of that RTO.
   2. In January 1998 (more than a year before Order No.
2000), several transmission-owning utilities in the Midwest
sought FERC’s approval for the transfer of operational con-
trol of their transmission facilities to an ISO known as
Midwest ISO (MISO), which would be organized as a non-
profit, non-stock corporation. See Midwest Indep. Transmis-
sion Sys. Operator, Inc., 84 FERC ¶ 61,231, 62,138–39 (1998)
(MISO Initial Approval). MISO would link up the transmis-
sion lines of the member transmission-owning utilities (MISO
Owners) into a single interconnected grid stretching across
the northern border of the U.S. from Michigan to eastern
Montana, and reaching as far south as Kansas City, Missouri
and Louisville, Kentucky. Under the MISO proposal, the
MISO Owners would retain ownership of and physically
operate and maintain their transmission facilities, subject to
MISO’s instructions. MISO would have functional control of
the transmission system, with responsibility for calculating
available transmission capability; receiving, approving, and
scheduling transmission service requests; and providing or
arranging for ancillary services under the tariff. MISO
                               6

would also serve as the system security coordinator for the
MISO Owners.
   The MISO Owners concurrently applied for approval of
MISO’s open access transmission tariff. See id. at 62,166.
Under the tariff, all customers would pay a single rate to use
the entire MISO transmission system, based on the volume of
power the customer carried on the system. The MISO
Owners did not, however, propose to bring all of their own
transmission loads immediately under that new open access
tariff. Several of the MISO Owners were required to provide
bundled retail service (generation and transmission) to con-
sumers at rates frozen by state legislation, state regulatory
agencies, or legal settlements. The MISO Owners proposed
that such bundled retail loads be brought under the MISO
tariff at the end of a six-year transition period, unless the
state regulatory authorities unbundled those loads sooner.
See id. at 62,167. Also, some MISO Owners had pre-existing
bilateral agreements with other utilities to provide wholesale
transmission service at fixed rates. The MISO Owners pro-
posed that loads under such grandfathered agreements also
remain outside of the tariff until the end of the transition
period. Thus, only new wholesale and unbundled retail trans-
mission loads would be immediately subject to the MISO
tariff.
  The MISO tariff included several mechanisms to recover
the costs associated with running MISO. Relevant to this
proceeding are Schedule 1 and Schedule 10. Under Schedule
1 of the tariff, MISO customers paid a charge for ‘‘Schedul-
ing, System Control and Dispatch Service.’’ MISO Open
Access Transmission Tariff, Original Sheet No. 117. This
charge covers MISO’s primary value-added service — man-
agement of the transmission grid. This Scheduling, System
Control and Dispatch Service charge, though, was to be paid
by the transmission customer directly to the MISO Owner
providing transmission service; at least at first, it was not to
be paid to MISO. Id.
  Schedule 10 of the MISO tariff, the ISO Cost Adder, was
designed to recover MISO administrative costs — the ‘‘costs
                                 7

associated with running the ISO that are not recovered under
Schedule 1.’’ MISO Open Access Transmission Tariff, Origi-
nal Sheet No. 136. Those costs included ‘‘costs associated
with the Security Center, including capital costs and ex-
penses, and administering the Tariff.’’ Id. The Cost Adder
was to be levied on a per megawatt basis and was calculated
monthly by dividing MISO’s eligible budgeted costs by the
expected eligible transmission load. So, for example, if
MISO’s expected eligible costs for June 2004 were $100,000,
and MISO anticipated one million megawatts of eligible load
for that same month, under Schedule 10, MISO would levy a
Cost Adder of 10 cents per megawatt on the eligible transmis-
sion load. The Cost Adder, though, was capped at 15 cents
per megawatt,1 with any unrecovered costs to be financed by
MISO and deferred to the end of the six-year transition
period, when the debt would be repaid on a five-year amorti-
zation schedule through a surcharge to all MISO customers.
Id. Sheet Nos. 136–37.
  Critically, the MISO tariff provided that only those trans-
mission loads subject to the tariff rates would pay the ISO
Cost Adder. Transmissions under state-mandated bundled
retail plans and grandfathered agreements thus were not
subject to the Cost Adder; only new wholesale loads and
unbundled retail loads would pay the Cost Adder.
  3. The Commission conditionally approved the establish-
ment of MISO and conditionally accepted the proposed MISO
tariff for filing. But having found that ‘‘[f]or the most part,
these rate terms have not been shown to be just and reason-
able and may be unjust, unreasonable, or unduly discrimina-
tory,’’ FERC suspended the MISO tariff, and set it for a
hearing. See MISO Initial Approval, 84 FERC at 62,167,
62,181–82. Among the issues set for a hearing was the ISO
Cost Adder. Id. at 62,167.
  1 As a point of comparison, in Order No. 888, FERC found that
the delivered cost of electricity to retail customers was up to $110
per megawatt in some regions of the country. See Order No. 888 at
31,651–52.
                              8

  Following a public hearing, the ALJ determined that the
proposed ISO Cost Adder was not just and reasonable be-
cause, inter alia, it did not apply to bundled retail loads or
grandfathered loads during the six-year transition period.
See Midwest Indep. Transmission Sys. Operator, Inc., 89
FERC ¶ 63,008, 65,045 (1999). The ALJ concluded:
    All of the Midwest ISO Participants’ transmission cus-
    tomers will benefit from Midwest ISO’s operational and
    planning responsibilities for the Midwest ISO transmis-
    sion system, as well as increased grid reliability of the
    transmission system. Therefore, to ensure that retail
    load will properly bear a fair [share] of the Midwest
    ISO’s costs, all long-term firm, bundled retail, and grand-
    fathered load should be included in the divisor in devel-
    oping the Cost Adder.
Id.
   Several utilities filed exceptions to the ALJ’s decision,
arguing that (1) the Cost Adder should not apply to bundled
loads because such loads were not obtaining benefits commen-
surate with the costs imposed by the Cost Adder; and (2)
applying the Cost Adder to bundled and grandfathered loads
would unlawfully trap costs with transmission owners.
FERC affirmed the ALJ’s findings and conclusions concern-
ing the Cost Adder, agreeing with the ALJ that ‘‘all users of
the grid operated by the Midwest ISO will benefit from the
Midwest ISO’s operational and planning responsibilities for
the Midwest ISO transmission system, as well as increased
grid reliability of the transmission system.’’ Midwest Indep.
Transmission Sys. Operator, Inc., 97 FERC ¶ 61,033, 61,169
(2001). The Commission concluded that it was appropriate
for the bundled and grandfathered loads to pay the Cost
Adder ‘‘to ensure that loads will properly bear a fair share of
the Midwest ISO’s costs.’’ Id. The Commission denied
rehearing, rejecting the MISO Owners’ cost-trapping claim
and explaining that any trapping of costs at the retail level
‘‘should be taken up with the appropriate state commissions.’’
Midwest Indep. Transmission Sys. Operator, Inc., 98 FERC
¶ 61,141, 61,414 (2002) (MISO II).
                                9

   The MISO Owners then sought judicial review in this court.
FERC moved for a voluntary remand, which we granted. In
its order on remand, FERC adhered to its prior ruling that
the bundled retail and grandfathered loads must pay the Cost
Adder on the same basis as new wholesale and unbundled
retail loads. See Midwest Indep. Transmission Sys. Opera-
tor, Inc., 102 FERC ¶ 61,192, 61,531–32 (2003) (MISO III).
After the Commission denied rehearing from its order on
remand, see Midwest Indep. Transmission Sys. Operator,
Inc., 104 FERC ¶ 61,012 (2003) (MISO IV), the MISO Own-
ers again sought review in this court.

                                II.
   ‘‘As a court of limited jurisdiction, we take seriously any
suggestion that we lack the authority to act.’’ Consumer
Elecs. Ass’n v. FCC, 347 F.3d 291, 296 (D.C. Cir. 2003). That
does not mean, however, that all such suggestions are serious.
FERC devotes 14 pages of its brief to arguing that the MISO
Owners lack standing to challenge the FERC orders compel-
ling them to pay the ISO Cost Adder, because the MISO
Owners have not shown that they will not be able to recoup
the Cost Adder charges at some point down the road. See
FERC Br. 17–31.
   FERC’s argument is tantamount to contending that a
homeowner whose house is destroyed by arson has not been
injured by the arsonist, if the house was adequately insured.
The challenged orders impose tangible costs on the MISO
Owners, who accordingly have standing to seek judicial re-
view.
   FERC also raises a related ripeness challenge, contending
that ‘‘[t]he availability of untested cost recovery mechanisms
makes this case unripe for judicial review at this juncture.’’
Id. at 30. Again, the fact that the MISO Owners might be
able to recoup the increased charges does not make the
challenge to their assessment unripe.2
  2As explained below, see infra 16–17, that is not to say that the
MISO Owners may now bring a challenge based on their assumed
inability to recoup the charges in the future.
                              10

   The jurisdictional speed bumps thus cleared, we can reach
the merits of FERC’s orders, which we review under the
familiar arbitrary and capricious standard. See 5 U.S.C.
§ 706(2)(A); Entergy Servs., Inc. v. FERC, 319 F.3d 536, 541
(D.C. Cir. 2003). We abide by the Commission’s factual
findings if they are supported by substantial evidence, see 16
U.S.C. § 825l(b), and we will affirm the Commission’s orders
so long as FERC ‘‘examine[d] the relevant data and articu-
late[d] a TTT rational connection between the facts found and
the choice made.’’ Motor Vehicle Mfrs. Ass’n v. State Farm
Mut. Auto. Ins. Co., 463 U.S. 29, 43 (1983); see also Public
Serv. Comm’n of New York v. FERC, 813 F.2d 448, 451 (D.C.
Cir. 1987). When FERC’s orders concern ratemaking, we
are ‘‘particularly deferential to the Commission’s expertise.’’
Association of Oil Pipe Lines v. FERC, 83 F.3d 1424, 1431
(D.C. Cir. 1996). Here we conclude that FERC’s order that
all MISO transmission loads must share in the ISO Cost
Adder comports with reasoned decisionmaking and therefore
deny the petitions for review.
   1. As a threshold matter, the MISO Owners argue that
FERC has switched course in these proceedings: FERC
originally approved MISO with bundled retail and grandfa-
thered loads excluded from the MISO tariff, but now has
ruled that these loads must share in the ISO Cost Adder.
The MISO Owners phrase this switch as a failure to comply
with Section 206 of the Federal Power Act, 16 U.S.C. § 824e.
That provision ‘‘permits the Commission TTT to initiate
changes to existing utility rates and practices.’’ Atlantic City
Elec. Co. v. FERC, 295 F.3d 1, 10 (D.C. Cir. 2002). Under
Section 206, however, ‘‘FERC must first prove that the
existing rates TTT are ‘unjust, unreasonable, unduly discrimi-
natory or preferential.’ ’’ Id. (quoting 16 U.S.C. § 824e(a)).
That, the Owners contend, FERC has failed to do.
   Section 206, however, is not implicated here because the
Cost Adder was never unconditionally accepted. In its deci-
sion that conditionally established MISO and conditionally
accepted the MISO tariff for filing, the Commission specifical-
ly set the issue of the ISO Cost Adder for a hearing pursuant
to its authority under Section 205 of the Federal Power Act,
                              11

16 U.S.C. 824d(e). See MISO Initial Approval, 84 FERC at
62,167. In considering the ISO Cost Adder, FERC was not
addressing an existing rate or practice, and so did not have to
make the findings required under Section 206.
   2. We can thus turn to the MISO Owners’ primary con-
tention — that FERC’s order does not comport with the ‘‘cost
causation principle.’’ We have described this principle as
‘‘requir[ing] that all approved rates reflect to some degree the
costs actually caused by the customer who must pay them.’’
KN Energy, Inc. v. FERC, 968 F.2d 1295, 1300 (D.C. Cir.
1992); Transmission Access Policy Study Group v. FERC,
225 F.3d 667, 708 (D.C. Cir. 2000); Pacific Gas & Elec. Co. v.
FERC, No. 03-1025, slip op. at 8–9 (D.C. Cir. July 9, 2004).
Not surprisingly, we evaluate compliance with this unremark-
able principle by comparing the costs assessed against a
party to the burdens imposed or benefits drawn by that
party. KN Energy, 968 F.2d at 1300–01 (citing Alabama
Elec. Coop., Inc. v. FERC, 684 F.2d 20, 27 (D.C. Cir. 1982)).
Also not surprisingly, we have never required a ratemaking
agency to allocate costs with exacting precision. See
Sithe/Independence Power Partners, L.P. v. FERC, 285 F.3d
1, 5 (D.C. Cir. 2002) (‘‘FERC is not bound to reject any rate
mechanism that tracks the cost-causation principle less than
perfectly’’). It is enough, given the standard of review under
the APA, that the cost allocation mechanism not be ‘‘arbitrary
or capricious’’ in light of the burdens imposed or benefits
received.
   We begin by recognizing that MISO is, of its Owners’ own
volition, a Commission-approved, Order No. 2000-compliant
RTO. See generally Midwest Indep. Transmission Sys. Op-
erator, Inc., 97 FERC ¶ 61,326 (2001) (concluding MISO met
the standards for RTO status under Order No. 2000). MISO
thus must have operational authority over all of the transmis-
sion loads wheeled across the MISO Owners’ transmission
facilities. See 18 C.F.R. § 35.34(j)(3) (‘‘The [RTO] must have
operational authority for all transmission facilities under its
control.’’); id. § 35.34(k)(1)(i) (‘‘The [RTO] must be the only
provider of transmission service over the facilities under its
control’’). This authority reaches even the bundled and
                              12

grandfathered loads that are not subject to MISO’s open-
access tariff transmission rates during the six-year transition
period. See MISO II, 98 FERC at 61,411, aff’d as modified
on remand, MISO III, 102 FERC at 61,532–33. This means
that the MISO Owners ‘‘must take all transmission services,
including transmission used to deliver power to bundled retail
customers, from Midwest ISO.’’ MISO III, 102 FERC at
61,532. The Owners therefore gain no traction in their
argument by portraying those loads as somehow not ‘‘on’’ the
MISO system.
  The MISO Owners nevertheless maintain that bundled and
grandfathered loads ‘‘will obtain only limited benefits from
the MISO’’ and the services bought with the Cost Adder.
Pet. Br. 27. To evaluate this claim, we start by reviewing the
services funded by the Cost Adder. According to the MISO
tariff, the ISO Cost Adder is set aside to pay for the ‘‘costs
associated with the Security Center, including capital costs
and expenses, and administering the Tariff.’’ MISO Open
Access Transmission Tariff, Original Sheet No. 136. The ISO
Cost Adder does not pay for ‘‘Scheduling, System Control and
Dispatch Service’’ — those costs are covered by a charge paid
directly to MISO Owners pursuant to Schedule 1 of the MISO
tariff. See id. (‘‘The costs associated with running the ISO
that are not recovered under Schedule 1 shall be recovered
through [the ISO Cost Adder].’’); see also Prepared Direct
Test. of Alan C. Heintz on behalf of the Midwest ISO
Participants, at 25 (‘‘Schedule 10 will recover the actual costs
associated with running the Midwest ISO that are not recov-
ered under Schedule 1. These costs will include the costs
associated with the Midwest ISO Security Center, including
capital costs and expenses, and the costs of administering the
Tariff.’’). It thus seems that the costs allocated by the Cost
Adder are primarily MISO’s startup expenses — particularly
those pertaining to the MISO Security Center — and certain
expenses pertaining to the creation and administration of
MISO’s open-access tariff.
  In Entergy Services, we recently observed that ‘‘upgrades
designed to ‘preserve the grid’s reliability’ constitute ‘system
enhancements [that] are presumed to benefit the entire sys-
                               13

tem.’ ’’ 319 F.3d at 543 (quoting Western Massachusetts
Elec. Co. v. FERC, 165 F.3d 922, 923, 927 (D.C. Cir. 1999)).
For their part, the MISO Owners do not contest this pre-
sumption. They readily concede that all transmission cus-
tomers — bundled, unbundled, grandfathered, whatever —
benefit from the enhanced reliability and security MISO
brings to the transmission grid. See Pet. Br. 36 (‘‘There is no
disagreement that bundled retail load receives some benefit
from the MISO’’); Oral Arg. Tr. of Paul M. Flynn, Counsel
for Petitioners MISO Owners, at 9 (Question: ‘‘[FERC]
determined that the ISO improved that reliability for those
with bundled loads as well, right?’’ Answer: ‘‘Oh, absolutely.
And we have no argument with that.’’); Prepared Rebuttal
Test. of Alan C. Heintz on behalf of the Midwest ISO
Participants, at 7 (Heintz Rebuttal Test.) (‘‘[T]he Midwest
ISO’s fulfillment of its responsibilities as a Security Coordina-
tor will also benefit other parties that are not directly receiv-
ing transmission service from the ISO.’’).
  The MISO Owners nevertheless contend that these benefits
account for only a small fraction of the Cost Adder expense.
Citing the testimony of their expert, the MISO Owners claim
that only five percent of the Cost Adder pays for MISO’s role
as regional reliability coordinator. Pet. Br. 36 (citing Heintz
Rebuttal Test. 7). Pointing to the facts that 60 to 70 percent
of the transmission load on the MISO system is bundled or
grandfathered load and that the Cost Adder is allocated
according to transmission load, the MISO Owners complain,
essentially, that bundled and grandfathered loads are not
getting their money’s worth from the Cost Adder. The
MISO Owners allege that, under FERC’s decision, they end
up paying 60 to 70 percent of the freight for five percent of
the benefits. MISO Owners argue that FERC should have
unbundled the expenses under Schedule 10, and charged
bundled loads only those costs incurred for their benefit.
Pet. Br. 39.
  Upon review of the record in this case, we conclude that
FERC reasonably allocated the Cost Adder to all loads using
the MISO transmission system, rather than just the unbun-
dled retail and new wholesale loads. The MISO Owners’
                              14

assertion that only five percent of the Cost Adder is attribut-
able to MISO’s regional reliability function misrepresents the
record evidence. Their expert witness said no such thing.
Rather, he testified:
    Although the expected infrastructure requirements for
    the Security Coordinator function are intertwined with
    those expected for the ISO’s other functions, it is my
    understanding that elimination of the Security Coordi-
    nator function might eliminate less than 5 percent of the
    Midwest ISO’s expected capital costs, and would elimi-
    nate little of the expected staffing requirements. This is
    because much of the staff and systems that are needed in
    any event to support the other functions will also support
    the Security Coordinator function.
Heintz Rebuttal Test. 7–8 (emphasis added).
    The MISO Owners’ conclusion that only five percent of the
Cost Adder is used to fund regional reliability logically does
not follow from their witness’s testimony that eliminating
security operations would reduce MISO’s capital expenditures
by less than five percent. Even accepting the MISO Owners’
implicit (but false) premise that the Cost Adder funds only
capital expenditures, capital expenditures — real estate, fix-
tures, furniture, etc. — almost always serve multiple pur-
poses; they are, in the words of the MISO Owners’ witness,
‘‘intertwined.’’ Id. at 7. Therefore, when a company elimi-
nates a particular function, that company will not necessarily
be able to reduce much in the way of its capital expenditures;
those capital expenditures may still be required to support
the company’s other functions. It is thus quite wrong to
assert, as the MISO Owners do, that only five percent of the
Cost Adder is devoted to security operations, simply because
eliminating that function would only reduce costs by that
amount. Far from demonstrating how little of the Cost
Adder is needed to fund MISO’s reliability and security
operations, the testimony elicited by the MISO Owners estab-
lishes the ‘‘intertwined’’ nature of capital expenditures, and
the corresponding difficulty of unbundling them. This is why,
among other very good reasons, the cost causation principle
                               15

does not require exacting precision in a ratemaking agency’s
allocation decisions. See Sithe/Independence Power Part-
ners, 285 F.3d at 5.
   In addition, the bundled and grandfathered loads draw
more benefits from MISO than simply enhanced transmission
security and reliability. As the MISO Owners themselves
recognized in their application to FERC to establish MISO,
benefits such as ‘‘an overall reduction in the costs of transmit-
ting energy within the region’’ and ‘‘large scale regional
coordination and planning of transmission’’ would redound to
all users of the transmission grid. See MISO Initial Approv-
al, 84 FERC at 62,140.
   Indeed, the costs covered by the ISO Cost Adder under
Schedule 10 are the administrative costs of having an ISO.
Transmission costs — the costs of using the system — are
allocated to users under Schedule 1. And even if they are not
in some sense using the ISO, the MISO Owners still benefit
from having an ISO. In this sense, MISO is somewhat like
the federal court system. It costs a considerable amount to
set up and maintain a court system, and these costs — the
costs of having a court system — are borne by the taxpayers,
even though the vast majority of them will have no contact
with that system (will not use that system) in any given year.
The public nevertheless benefits from having a system for the
prompt adjudication of criminal offenses and the orderly
resolution of civil disputes. Litigants bear some of the costs
of using this system through the payment of filing fees and
court costs. They, like utilities transmitting power under the
MISO open access tariff who pay according to Schedule 1, are
paying for the specific benefit of using the court system.
The MISO Owners’ position is tantamount to saying that if
they are not a litigant, they should not be made to pay for
any of the costs of having a court system. Since the MISO
Owners do, in fact, draw benefits from being a part of the
MISO regional transmission system, FERC correctly deter-
mined that they should share the cost of having an ISO.
   For all these reasons, we conclude that FERC’s allocation
of the Cost Adder to all users of the MISO grid, according to
                                 16

transmission volume, meets the minimum standards for rea-
soned decisionmaking required by the APA.3
   3. The MISO Owners alternatively contend that FERC,
by levying the Cost Adder on bundled retail and grandfa-
thered loads, created an ‘‘unnecessary risk of an unlawful
trapping of costs.’’ Pet. Br. 44 (citing, inter alia, Nantahala
Power & Light Co. v. Thornburg, 476 U.S. 953, 971–72
(1986)). Specifically, the MISO Owners complain that their
bundled retail rates and grandfathered contracts are essen-
tially immutable, so that when the Cost Adder increases their
cost of transmission under those contracts, those new costs
are trapped with utilities, rather than passed on to consum-
ers.
  We have recognized that a ‘‘cost-trapping’’ claim can accrue
when ‘‘a state exercises its ‘jurisdiction over retail sales to
prevent the wholesaler-as-seller from recovering the costs of
paying the FERC-approved rate.’ ’’ Louisiana Public Serv.
Comm’n v. FERC, 184 F.3d 892, 899 (D.C. Cir. 1999) (quoting
Nantahala Power & Light, 476 U.S. at 970). The MISO
Owners here make something of a reverse cost-trapping
argument — FERC has trapped costs under rates that are
set by states or other contractual partners and has thereby
  3  We have also considered the contention of MISO Owners Louis-
ville Gas & Electric Company and Kentucky Utilities Company
(LG&E/KU) that FERC failed to meaningfully address their argu-
ment that application of the ISO Cost Adder to them ‘‘is especially
arbitrary and egregious’’ because they bring low-cost power to
MISO, Pet. Br. 59, and they regarded the transition period —
including exemption of their bundled retail and grandfathered loads
from the Cost Adder — as a fair trade for this benefit, see id. at 59–
69. This is simply a variation on the MISO Owners’ general
argument, and FERC rejected it by ‘‘reiterat[ing] that bundled
retail and grandfathered wholesale loads, including LG&E/KU’s,
benefit from the services provided by Midwest ISO, and, therefore
TTT must be included in the calculation of the ISO Cost Adder.’’
MISO IV, 104 FERC at 61,030 (footnote omitted); see also id. at
61,029 (FERC ‘‘cannot be bound by the unreasonable assumption
that it will approve a proposed tariff provision as just and reason-
able simply because an entity relied on that provision.’’).
                              17

diminished the MISO Owners’ return. This claim fails for at
least two reasons.
   First, the ‘‘risk’’ the MISO Owners complain about is just
that — a risk. It is an essential element of any cost-trapping
claim that real costs actually be trapped — stuck with the
regulated entity — resulting in reduced profits. The MISO
Owners cannot presently point to any loss resulting from
FERC’s alleged cost-trapping, because it is not known what
action will be taken by state regulators in response to the
imposition of the ISO Cost Adder.
   More fundamentally, whatever the fate of any future cost-
trapping claim raised in response to prospective state regula-
tory action, the reverse cost-trapping argument the Owners
now seek to raise fails as a legal theory. The decision that
first approved cost-trapping claims, Nantahala Power &
Light, was based on the Supremacy Clause and principles of
federal preemption; the Court held that the state regulatory
authority, by increasing the utility’s cost of service after
FERC had established a cost-based rate for the utility,
impermissibly interfered with FERC’s authority to set just
and reasonable rates. See 476 U.S. at 970–72. We have
never, though, recognized as valid a reverse cost-trapping
claim of the variety brought by the MISO Owners — where it
is a federal regulatory action that is purportedly interfering
with a state’s regulatory scheme. Federal preemption and
the Supremacy Clause do not circumscribe FERC’s authority;
those principles operate to prevent the states from taking
regulatory action in derogation of federal regulatory objec-
tives. If, as the MISO Owners fear, the FERC-approved
application of the Cost Adder to bundled and grandfathered
loads results in ‘‘trapped’’ costs, their initial recourse is to
their state regulators and contractual partners armed with
principles of federal preemption and the Supremacy
Clause — not to FERC.

                            * * *
  The petition for review is denied.