# Bp West Coast Products, LLC v. Federal Energy Regulatory Commission and United States of America, Sfpp, L.P., Intervenors

> Court of Appeals for the D.C. Circuit · October 4, 2004 · 374 F.3d 1263

URL: https://www.frixlaw.com/law-library/cases/786887

## Case

- **Full name:** BP WEST COAST PRODUCTS, LLC, Petitioner, v. FEDERAL ENERGY REGULATORY COMMISSION and United States of America, Respondents. SFPP, L.P., Et Al., Intervenors
- **Court:** Court of Appeals for the D.C. Circuit
- **Decided:** October 4, 2004
- **Citations:** 374 F.3d 1263; 362 U.S. App. D.C. 438
- **Precedential status:** Published
- **Opinion:** Opinion
- **Judges:** Sentelle, Rogers, Roberts
- **Cited by:** 27 later opinions in the Frix Law Library

## Citator (automated)

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## Opinion text

Opinion for the Court filed PER CURIAM.
Introduction
The consolidated petitions before us seek review of four opinions of the Federal Energy Regulatory Commission (“FERC” or “the Commission”):
1.
SFPP, L.P.,
Opinion No. 435, 86 FERC ¶ 61,022 , 1999 WL 12216 (1999) (“Opinion No. 435”);
2.
SFPP, L.P.,
Opinion No. 435-A, 91 FERC ¶ 61,135 , 2000 WL 640584 (2000) (“Opinion No. 435-A”);
3.
SFPP, L.P.,
Opinion No. 435-B, 96 FERC ¶ 61,281 , 2001 WL 34076552 (2000) (“Opinion No. 435-B”); and
4.
SFPP, L.P.,
97 FERC ¶ 61,138 , 2001 WL 1379466 (2001) (“Clarification and Rehearing Order”).
In these opinions FERC considered the tariffs of SFPP, L.P., and complaints and other filings by shipper customers of SFPP. SFPP, L.P., both a petitioner and an intervenor-respondent in the consolidated dockets, operates pipelines that transport petroleum products in Texas, New Mexico, Arizona, California, Nevada, and Oregon. SFPP’s operation includes a West Line and an East Line. The West Line consists of pipelines extending from Watson Station in Los Angeles, California, into Arizona to Phoenix and Tucson, and connects at Colton, California, with another pipeline system extending to Las Vegas. SFPP’s East Line consists of pipelines from El Paso, Texas to Tucson and Phoenix. The orders under review consider, set, and otherwise govern rates on both lines. We consider three separate sets of petitions: the petition of SFPP, L.P.; the petition of the West Line Shippers (“WLS”); and the petition of the East Line Shippers (“ELS”). Petitioners and Intervenors include the following: BP West Coast Products LLC (“BP WCP”; formerly ARCO Products Company); Chevron Products Company (“Chevron”; including the former Texaco Refining and Marketing, Inc.); ConocoPhillips Company (“ConocoPhillips”); ExxonMobil Oil Corporation (“ExxonMobil”; formerly Mobil Oil Corporation); Navajo Refining Company, L.P. (“Navajo”); Western Refining Company, L.P. (“Western”); Ultramar Inc. (“Ultramar”); Valero Energy Corporation (“VEC”); Valero Marketing and Supply Company (“Valero”); and SFPP, L.P. (“SFPP”).
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The administrative proceedings before FERC began with tariff filings by SFPP for both East and West Lines. The lengthy, complex, and convoluted proceedings that followed included complaints and/or protests filed by shippers on the two lines, as well as investigation into SFPP’s tariff filings by FERC’s Oil Pipeline Board. The issues are further complicated by novelty in that this is the first oil pipeline case in which the “changed circumstances” standard of the Energy Policy Act of 1992 (“EPAct”) has arisen for litigation. Energy Policy Act of 1992, Pub. L. No. 102-486, 106 Stat. 2776 (codified as 42 U.S.C. §§ 1320-656 (2003)). While we will not detail the administrative proceedings before FERC’s administrative law judge and the full Commission as we discuss them at length in the analyses that follow, we note that issues presented for review include, among other things, the important question of application of the grandfathering principle under the new EPAct, the allocation
of
litigation costs between the East and West Lines, tax pass-through problems involving non-taxed subsidiaries of taxable entities, the payment of reparations after a finding of unjust or unreasonable rates, and the correct determination of capital structure to determine a starting rate base. The reader is duly warned.
For reasons set forth more fully below, we are able to affirm many of FERC’s answers to specific issues, but because we find error in several fundamental areas, we order the decisions under review vacated and remand the matter for further proceedings consistent with this opinion.
I. The West Line
A.
Grandfathering of Rates under the EPAct
Section 1803 of the EPAct limits the ability of shippers to challenge pipeline rates in effect at the time of the enactment of the EPAct. Section 1803 provides that any oil pipeline rate that was “in effect” for a full year before the EPAct’s enactment on October 24, 1992, and was not subject to “protest, investigation, or complaint” during that 365-day period, is “deemed to be just and reasonable.” EPAct § 1803(a)(1). These “grandfathered” rates are categorically immune from challenge in a complaint proceeding under Section 13 of the Interstate Commerce Act (“ICA”), 49 U.S.C. app. § 13(1) (1988) (repealed),
1
except when:
(1) evidence is presented to the Commission which establishes that a substantial change has occurred after the date of the enactment of this AcW
(A) in the economic circumstances of the oil pipeline which were a basis for the rate; or
(B) in the nature of the services provided which were a basis for the rate; or
(2) the person filing the complaint was under a contractual prohibition against the filing of a complaint which was in effect on the date of enactment of this Act....
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Id.
§ 1803(b). In the post-EPAct world, the analysis of a pipeline rate challenge thus proceeds in two steps: first, FERC determines whether the rate in question is grandfathered; if it is, FERC then asks whether the rate falls within either of the exceptions outlined in Section 1803(b). The Commission may not alter a grandfathered rate that does not fall within an exception.
B.
Grandfathering of West Line Rates
The WLS contend that none of the West Line rates are grandfathered, and further argue that even if the rates are grandfathered, their challenges fall within the exceptions set out in Section 1803(b). We examine each of these contentions in turn.
1.
Rate “In Effect”for One Year
To be eligible for grandfathering, a pipeline rate must have been “in effect for the 365-day period ending on the date of the enactment of this Act [October 24, 1992].” EPAct § 1803(a)(1). Thus, to be grandfathered, a rate must have been “in effect” on October 25, 1991, and have remained in effect at least until the enactment of the EPAct.
The WLS do not contest this element with regard to the bulk of the West Line rates. Nor could they; the West Line rates became effective in 1989 pursuant to a settlement terminating a 1985 rate proceeding.
See
Opinion No. 435, 86 FERC at 61,057;
Southern Pac. Pipe Lines, Inc.,
45 FERC ¶ 61,242 , 1988 WL 246514 (1988) (order approving settlement). The WLS do, however, challenge the eligibility for grandfathering of certain improvements to the West Line made after October 1991.
a.
East Hynes Origination Point
In July 1992, SFPP made revisions to its Tariffs Nos. 15, 16, and 17 to add a new origination point on its West Line — the East Hynes station in Los Angeles County, California — and to add a rate for shipping services from that new origination point to Arizona. The rate came into effect in October 1992. The rate, however, was not new; it was the same as the rates from SFPP’s two other source points in the Los Angeles area. Examining this situation, the Commission concluded that the rates from the East Hynes station qualified for grandfathering because the July 1992 “filing did not involve a change to a rate or service SFPP was providing at the time the EPAct was enacted.” Opinion No. 435, 86 FERC at 61,063. SFPP’s revision to its tariffs “only added another tap within an existing rate cluster.... No rate ... was changed, and there was no change in the products transported or the services provided.”
Id.
The question essentially boils down to the Commission’s interpretation of the term “rate” in Section 1803. As this is the first ease to be litigated under the new standards of the EPAct, we must consider the level of deference — if any — to which FERC’s interpretations of the EPAct are entitled. It is true, as some petitioners have noted, .that the EPAct does not expressly confer rulemaking authority on the Commission. Section 1803 of the EPAct does, though, clearly contemplate that the Commission will enforce the terms and conditions of the statute through formal adjudications.
See
EPAct § 1803(b) (referencing “proceeding instituted as a result of a complaint”). When Congress authorizes an agency to adjudicate complaints arising under a statute, the agency’s interpretations of that statute announced in the adjudications are generally entitled to
Chevron
deference.
See United States v. Mead Corp.,
533 U.S. 218, 229 , 121 S.Ct. 2164, 2172 , 150 L.Ed.2d 292 (2001) (“[A] very good indicator of delegation meriting
Chevron
treatment [is] express congres
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sional authorizations to engage in the process of rulemaking or adjudication that produces regulations or rulings for which deference is claimed.”);
see also Trans Union Corp. v. FTC,
81 F.3d 228, 230 (D.C.Cir.1996) (“[W]e have expressly held that
Chevron
deference extends to interpretations reached in adjudications as much as to ones reached in a rulemaking.” (citing
Midtec Paper Corp. v. United States,
857 F.2d 1487, 1497 (D.C.Cir.1988))). We see no reason to accord any less deference to FERC’s interpretations of the EPAct.
Under the familiar
Chevron
two-part inquiry, we first ask whether Congress has directly spoken to “the precise question at issue.”
Chevron U.S.A. Inc. v. Natural Res. Def. Council, Inc.,
467 U.S. 837, 842 , 104 S.Ct. 2778, 2781 , 81 L.Ed.2d 694 (1984). If it has, that is the end of the inquiry; we “must give effect to the unambiguously expressed intent of Congress.”
Id.
at 843 , 104 S.Ct. at 2782 . If Congress has not spoken so precisely, though, we reach the second step, and will 'defer to any reasonable interpretation of the statute by the agency.
Id.
Not surprisingly, Congress did not have occasion to confront the specific question
of
whether the addition of a new source point on an existing rate cluster would constitute a new rate. We thus proceed to the second step of
Chevron,
and inquire whether the Commission’s construction is a reasonable one. It is. It is certainly permissible to conclude that the addition of a tap to an existing rate structure, completed without any change in the existing shipping rates, does not constitute a new rate. To employ an analogy that we find helpful, in adding the East Hynes station to its West Line, SFPP merely added an on-ramp to its existing expressway. We think that the Commission’s conclusion reflects a permissible interpretation of the statute and thus affirm its holding that the rate for shipping from East Hynes is eligible for grandfathering.
b.
Watson Station Enhancement Facility
Watson is the primary origin point for West Line shipments to Phoenix and Tucson. In 1989, SFPP notified its shippers that, starting in 1991, the minimum pumping rate and pressure from Watson Station would increase. SFPP gave its shippers the option of providing their own pressurization facilities by a date certain, or using, for a surcharge, a facility built by SFPP. By late 1991, most of SFPP’s shippers had contracted to use SFPP’s new enhancement facility, and on November 1, 1991, SFPP initiated the enhancement services.
See
Opinion No. 435, 86 FERC at 61,074;
In re SFPP, L.P.,
80 FERC ¶ 63,014 , 65,-156 & n. 405, 1997 WL 698344 (1997) (“ALJ Decision”). SFPP, though, never filed those contracts with the Commission, because it believed its enhancement services were beyond the reach of FERC’s jurisdiction.
See
Opinion No. 435, 86 FERC at 61,074. The Commission, however, concluded otherwise and ordered SFPP “to file a rate equal to the historic charge in the shipper contracts.”
Id.
at 61,076.
Despite FERC’s concession that “Section 1803 only addresses rates that were on file with the Commission,” Opinion No. 435-A, 91 FERC at 61,502, and its acknowledgment that the enhancement rates had never before been filed, FERC nevertheless concluded that, because “the charges for the Watson Station facilities are part of enforceable contracts,” the rates were “the equivalent of a lawful, effective rate.” Opinion No. 435, 86 FERC at 61,076. The Commission reasoned that because all the Watson enhancement rate contract charges “were in effect before October 24, 1992,” the ship
*1274
pers challenging those charges had to establish “substantially changed circumstances.”
Id.
at 61,075, 61,076. The fact that no statute permitted a shipper to challenge an unfiled rate before the Commission did not matter. For “if [the rates] had been filed ..., it is clear that they would have been grandfathered because there was no challenge to them during the 12 months proceeding [sic] the enactment of the Act.” Opinion No. 435-A, 91 FERC at 61,502.
We find the Commission’s reasoning on this point to be fundamentally flawed, and vacate this portion of its order. First, if FERC is indeed correct in its interpretation that Section 1803 applies only to filed rates, the Commission may not grandfather unfiled rates on the assumption that if the rates had been filed, no challenge would have been brought. The Commission may not regulate rates as if they existed in a world that never was. It must take the rates as it finds them, and here, FERC found them unfiled. If FERC interprets Section 1803 to apply only to filed rates, then it may not extend the benefits of that provision to unfiled rates based on speculation about what would have happened had they in fact been filed. Invoking the so-called “filed rate” doctrine — which “forbids a regulated entity to charge rates for its services other than those properly filed with the appropriate federal regulatory authority,”
Arkansas Louisiana Gas Co. v. Hall,
453 U.S. 571, 577 , 101 S.Ct. 2925, 2930 , 69 L.Ed.2d 856 (1981) — the WLS argue that the pipeline’s failure to file a Watson enhancement rate tariff with the Commission precludes the Commission’s treatment of the unfiled rate as grandfathered. Our disposition of this issue — which is based on the Commission’s flawed reasoning, and not a flawed conclusion — does not require us to decide definitively whether Section 1803 of the EPAct applies only to filed rates.
Second, Opinion No. 435 suggests that any rate agreed upon before the EPAct’s enactment on October 24, 1992 could be grandfathered.
See
Opinion No. 435, 86 FERC at 61,075 (“The clear purpose of the EPAct’s grandfathering provisions is to insulate pipelines from challenges to ... rates ... if those charges were in effect before October 24, 1992.”). Section 1803, though, allows grandfathering of only those rates that were in effect (and unchallenged) for at least 365 days prior to the date of enactment of EPAct. EPAct § 1803(a). Even if we assume as a general proposition that Section 1803 applies to unfiled rates, other statements sprinkled throughout Opinion No. 435 suggesting that some of the rates were contracted for after the 365-day window had closed would remain problematic.
See
Opinion No. 435, 86 FERC at 61,075 (“the contracts were entered into voluntarily by the parties, mostly before the end of 1991”);
id.
(“all the relevant contracts were required to be, and had been, executed well before June 1, 1992”). If the Commission allows Section 1803 to apply to unfiled rates, those rates, to be grandfathered, must be in effect for at least 365 days prior to the EPAct’s enactment. The reasoning of Opinion Na 435 gives us no comfort that this was the case. Without such an assurance, we cannot affirm the Commission’s conclusion that the Watson enhancement rate is subject to grandfathering.
c.
Turbine Fuel Service
In December 1992, SFPP filed its Tariff No. 18, proposing the transportation on its West Line of a new product, turbine fuel (also known as jet fuel). The rate for the new turbine fuel service was equal to other grandfathered rates in Tariff No. 18
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that had been in effect since 1989. The shippers argue that because the turbine fuel rate was not initiated until 1992 — long after the grandfathering window had closed (indeed, after the EPAct had been enacted) — the rate cannot be grandfathered. The Commission does not contest this; it recognized that the turbine fuel service was new, and therefore could not be grandfathered.
Id.
at 61,063. It nevertheless foreclosed further challenge to the turbine fuel rate, concluding, as a
substantive
matter, that the turbine fuel rate was just and reasonable.
Id.
at 61,078. The Commission reasoned that because the turbine fuel rate was equal to other Tariff No. 18 rates that had been deemed just and reasonable, “there is no basis for providing a different rate level for turbine fuel at this time.”
Id.
That analysis falls far short of the mark. The fact that the Tariff No. 18 rates were
deemed
just and reasonable does not mean that the rates actually
are
just and reasonable. Perhaps if the Commission had undertaken a substantive review
of
the reasonableness of the West Line rates listed in Tariff No. 18, then its conclusion that the turbine fuel rate is reasonable — because it is equal to those rates — might be supportable. But here, the West Line rates had been “deemed just and reasonable” by operation of law — solely because they had persisted without challenge for one year prior to the enactment of the EPAct. The turbine fuel rate, not itself eligible for grandfathering, cannot simply piggyback on the grandfathered status of other rates. The Commission’s contrary conclusion reflects a fundamental misapprehension of the nature and purpose of the grandfathering provisions of the EPAct. The requirements for grandfathering — the rate must be in effect and not subject to challenge for the year prior to the EPAct’s enactment — are not proxies for actual reasonableness. Those requirements instead operate principally as a means to constrain litigation over pre-EPAct pipeline rates. The fact that the turbine fuel rate is equal to other Tariff No. 18 rates thus says nothing about that turbine fuel rate’s substantive reasonableness. The Commission’s declaration that, as a
substantive
matter, the turbine fuel rate was just and reasonable — a conclusion reached without the benefit of any substantive review of the underlying cost of service and rate of return — was an arbitrary and capricious exercise of the Commission’s authority and cannot stand.
2.
Complaints, Protests, or Investigations
While the WLS concede that most of the West Line rates were in effect for the required year prior to the EPAct’s enactment, they contend that no West Line rate is eligible for grandfathering because each of them was “subject to protest, investigation, or complaint” during that same one-year window. In support of their argument, the WLS point principally to protests filed by shippers El Paso Refinery, L.P. (“EPR”) and Chevron, and an investigation opened by the Oil Pipeline Board (“OPB”) pursuant to those protests. In October 1993, the Commission rejected these arguments, holding that the West Line rates were “presumed just and reasonable” and, therefore, a successful challenge had to “prove the existence of the extraordinary circumstances set forth in section 1803 of the Energy Policy Act.”
SFPP, L.P.,
66 FERC ¶ 61,028 , 61,378, 1993 WL 390971 (1993);
see also SFPP, L.P.,
66 FERC ¶ 61,210 , 1994 WL 48050 (1994) (denying rehearing).
What does it mean for “the rate” to be “subject to protest, investigation, or complaint”? EPAct § 1803(a). The WLS
*1276
maintain that a general attack on a tariff is sufficient to challenge all the rates and activities described therein.
See
WLS Br. 14 (“a protest of a tariff filing did subject all rates in the tariff to review”). The Commission, though, in ruling that the shippers’ pleadings did not challenge the West Line rates, interpreted this clause of Section 1803 to require that the protest, investigation, or complaint specifically challenge the reasonableness of the rate in question.
See SFPP, L.P.,
65 FERC at 61,378 n.14 (while Chevron’s protest did include “a request for suspension of revised tariff no. 16, which contains ... only west line rates,” the protest “pled no concerns with the existing rates set forth in this tariff’). The WLS object to FERC’s interpretation on a general level, arguing that it grafts onto the statute a particularity requirement not found in its text. Here, too, we find the
Chevron
deference that we must accord to the agency’s interpretation to be dispositive. Because we cannot say that the Commission’s adjudicative interpretation is an impermissible reading of the statute — the statute provides, after all, that it is “the rate” (not the tariff) that must be subject to “protest, investigation, or complaint” — we defer to the Commission’s interpretation. And with that interpretation in mind, we turn to the particular contentions of the WLS.
a.
West Line Shipper Protests
On September 4, 1992, EPR, an East Line shipper, filed a protest to SFPP’s Tariffs Nos. 15 and 16, and followed with three supplements that same month, one of which requested the suspension of Tariffs Nos. 15 and 16 and that the Oil Pipeline Board (“OPB” or “Board”) open an investigation into the same. That same month, Chevron, which shipped on both the East and the West Line, filed a protest to Tariffs Nos. 15 and 16, also calling for their suspension and investigation.
The WLS contend that because EPR’s and Chevron’s protests challenged Tariff No. 16 — which listed only West Line rates —• those protests had challenged the West Line rates. The Commission rejected this contention, looking beyond the relief requested by the protests to the shippers’ substantive arguments for that relief. Examining the relevant pleadings, the Commission concluded that the protesting shippers “raised concerns with only three matters — flow reversal, prorationing, and existing rates on SFPP’s east line.”
Id.,
65 FERC at 61,378. As “[njothing within the four corners of these protests indicate[d] a concern with the existing rates on SFPP’s west line,” the Commission rejected those protests as a basis for denying grandfathered status to the West Line rates.
Id.
Our examination of the relevant pleadings convinces us that the Commission correctly concluded that EPR and Chevron did not challenge the reasonableness of the West Line rates in their protests to SFPP’s Tariffs No. 15 and 16. The EPR and Chevron pleadings scarcely mention the West Line at all, let alone mount an attack on the reasonableness of its rates. The
only
mention of the West Line rates is found in EPR’s first supplement to its protest: “Santa Fe’s proposed Tariff Nos. 15 and 16 retain Santa Fe’s previously effective rates for service on its East Line and West Line systems, but represent the first tariffs under which product will flow in a reversed direction on the ‘Six-Inch Line’ portion of the East Line system from Phoenix to Tucson.”
In re SFPP, L.P.,
Supplement to Protest of El Paso Refinery, L.P., 1-2 (Sept. 9, 1992) (emphasis omitted). This statement obviously concerns the flow reversal on the Phoenix-Tucson pipe — not the reasonableness of
*1277
West Line rates. Chevron’s protest, as the Commission noted, “simply fails to contain any statement indicating a challenge to existing rates on SFPP’s west line.”
SFPP, L.P.,
65 FERC at 61,378. The Commission thus reasonably concluded that these protests by East Line shippers were insufficient to render the West Line rates “subject to protest.” EPAct § 1803(a).
2
b.
Oil Pipeline Board Investigation
On September 29,1992, in response to the protests filed by EPR and Chevron, the OPB, pursuant to its authority under Section 15(7) of the ICA, 49 U.S.C. app. § 15(7) (1988), opened an investigation of SFPP’s rates listed in revised Tariffs Nos. 15, 16, and 17, suspended the tariffs for one day, and imposed refund obligations on SFPP.
SFPP, L.P.,
60 FERC ¶ 62,252 , 1992 WL 238197 (1992).
3
In April 1993, the Commission vacated the suspension orders and the refund obligations.
SFPP, L.P.,
63 FERC ¶ 61,014 , 1993 WL 181572 (1993). Observing that the protests against the tariffs did not challenge any change in a listed rate or practice (such as the addition of the East Hynes origination point or the turbine fuel service), but rather attacked only existing, unchanged rates and policies (the East Line rates and the flow reversal and prorationing practices), the Commission concluded that the OPB lacked authority to. open an investigation under Section 15(7) of the ICA, which permits the Board only to investigate newly filed rates or practices.
Id.
at 61,125 (“It was not appropriate for the Board to suspend the proposed tariff changes and initiate an investigation under section 15(7) when the focus of the protest was existing, unchanged, portions of the tariff.”); 49 U.S.C. app. § 15(7) (1988) (limiting application to “any schedule stating any
new
individual or joint rate ... or charge”) (emphasis added). The Commission held that the case should continue as a complaint proceeding before the Commission under ICA Section 13(1),
id.
§ 13(1), and be limited to the issues properly raised by EPR, Chevron, and the intervenors.
SFPP, L.P.,
63 FERC at 61,125. But as the Board “does not possess delegated authority to order initiation of a section 13(1) proceeding,” the Commission vacated the tariff suspensions and the refund obligations.
Id.
The Commission eventually terminated the Board’s suspension docket entirely, stating that matters would proceed only in the instant complaint docket.
SFPP, L.P.,
63 FERC ¶ 61,275 , 1993 WL 212867 (1993). And based on its conclusion that the OPB’s investigation had been
*1278
unlawfully initiated, the Commission determined that SFPP’s West Line rates were not “subject to investigation” for grandfathering purposes.
SFPP, L.P.,
66 FERC at 61,480.
Parsing with care the words of the Commission’s countermand of the Board, the WLS argue that the Commission never formally vacated the Board’s investigation of the SFPP’s Tariffs Nos. 15-18, and thus the rates within those tariffs — including the West Line rates — remained subject to investigation in 1992, precluding grandfathered status. We, like the Commission, are unpersuaded. First, while the WLS are quite right that the Commission did not, in its ordering clauses, vacate the Board’s investigation, the shippers’ interpretation of the Commission’s action runs head-on into the Commission’s statement that it was inappropriate “to suspend the proposed tariff changes and
initiate an investigation
under section 15(7).”
SFPP, L.P.,
63 FERC at 61,125 (emphasis added). Moreover, the shippers offer no explanation how such an investigation by the Board could proceed in light of the Commission’s order that the case would continue as a Section 13(1) complaint. But even if common sense bowed to formalism and the Board’s investigation remained technically open, the scope of the Board’s investigation — lawful only insofar as it enforces ICA Section 15(7) — must be limited to newly tariffed rates or practices.
See
49 U.S.C. app. § 15(7) (1988). As SFPP’s tariffs made no changes to the West Line rates (except to add the Watson enhancement and the turbine fuel services), the Board could not have investigated the West Line rates.
We therefore conclude that FERC reasonably determined that the West Line rates (except, as noted above, for the Watson Station enhancement and turbine fuel rates) were grandfathered and therefore deemed just and reasonable under the terms of Section 1803(a) of the EPAct.
C.
Exceptions to Grandfathering
We turn now to the WLS’ contention that the rates fall within the exceptions outlined in Section 1803(b) and therefore are still open to challenge under the ICA. Section 1803(b) permits a shipper to challenge a grandfathered rate if the shipper establishes either that (1) there has been a “substantial change” in the economic circumstances or services provided that “were a basis for the rate”; or (2) “the person filing the complaint” was under “a contractual prohibition against the filing of a complaint” on the date of the enactment of the EPAct. EPAct § 1803(b). The complaining shipper bears the burden of proving the existence of one of the circumstances triggering an exception. The Commission concluded that the WLS had not met either requirement.
See SFPP, L.P.,
68 FERC ¶ 61,105 , 61,581, 1994 WL 380738 (1994) (contractual prohibition); Opinion No. 435, 86 FERC at 61,064-71 (changed circumstances). The shippers were therefore barred by the EPAct from challenging the grandfathered West Line rates. The WLS appeal both rulings.
1.
Substantially Changed Circumstances
Before the ALJ and the Commission, the WLS argued that there were five circumstances that had substantially changed so as to permit a challenge to the grandfathered West Line rates, including increased throughput on the West Line and the impact of the Commission’s
Lakehead
decisions on SFPP’s income tax cost allocation. The ALJ rejected all the substantial change arguments.
See
ALJ Decision, 80 FERC at 65,192-96. Concerning the claim based on throughput, the ALJ concluded that the evidence of a forty-percent increase in throughput from EPAct’s en
*1279
actment in October 1992 to 1995 (the last year for which data was obtained), by itself, could not prove a change in economic circumstances.
Id.
at 65,194. Missing, according to the ALJ, was any evidence demonstrating that the increase in throughput produced higher revenues and profits for SFPP.
Id.
The Commission affirmed the holdings of the ALJ on each of the WLS’ claims of substantial change,
see
Opinion No. 435, 86 FERC at 61,064-71, but, with respect to the throughput claim, did so on somewhat different reasoning,
see id.
at 61,067-69. The Commission found that the ALJ had erred by measuring change from the date of enactment of the EPAct, and by using data generated after the filing of the shippers’ complaint.
Id.
Determining whether there has been a substantial change in economic circumstances providing, the basis for the rate, the Commission held, requires comparing (a) the period before the rate first became effective (the basis for the rate) with (b) the period starting on the date of enactment and ending on the date of the complaint.
Id.
The WLS’ substantial change claim based on increased throughput failed because the shippers measured changed circumstances against the “wrong base period” and with post-complaint evidence.
Id.
at 61,069. To establish a substantial change, FERC held, the shippers should have compared the period before the West Line rates became effective in 1989 to the period between October 24, 1992 (EPAct’s enactment) and August 7, 1993 (the date of Chevron’s complaint).
The shippers contest neither the Commission’s interpretation of the substantial change provision of EPAct, nor its conclusion that the shippers failed to demonstrate a substantial change under that standard. The WLS do, however, maintain that the Commission’s ruling employed a “newly articulated standard” and that they-are, therefore, entitled to a remand so that they may have an opportunity to litigate under the Commission’s “new” evidentiary requirements. WLS Br. 23. We reject this contention.
Even before the Commission announced this interpretation, the correct points of comparison in’ a substantial change analysis were clear from the face of the statute. The statute requires a shipper to show a change in economic circumstances “which were a basis for the rate.” EPAct § 1803(b). As the Commission noted in its Opinion No. 435, this phrase could only mean “the basis upon which the rate was last considered to be just and reasonable, either as a filed rate, a settlement rate, or one for which the Commission has made a legal determination.” Opinion No. 435, 86 FERC at 61,068. Any other moment in time would lack “correlation to the economic circumstances that were the basis of the rate at the time it was designed.”
Id.
The textual clues to the second point of comparison are perhaps less obvious but no less certain. The statute provides that “[n]o person may file a complaint ... unless ... evidence is presented ... which establishes that a substantial change has occurred after the, date of ... enactment.” EPAct § 1803(b). From the “after the date of enactment” language we are given the earliest point at which a shipper may show a substantial change. The closing date for evidence is the day the complaint is filed; this conclusion follows from the language providing that no “complaint” may be filed unless “evidence is presented” with the complaint that demonstrates that a substantial change “has occurred.” As the Commission stated, “[i]t is difficult to see how language that so explicitly uses the past tense could apply to evidence that would be developed at some indeterminate time after the complaint is filed.” Opinion
*1280
No. 435, 86 FERC at 61,069. Because the foregoing requirements of the statute are clear from its face, the shippers had adequate notice of the standard they were required to meet.
See, e.g., Midtec Paper Corp. v. United States,
857 F.2d 1487, 1510 (D.C.Cir.1988) (rejecting petitioner’s argument that it had inadequate notice specific evidence was required to support its complaint where the text of the regulations at issue “clearly indicates” that such evidence was to be considered).
4
The WLS also argue that the Commission erred in rejecting their argument that the Commission’s decision in
Lakehead Pipe Line Co., L.P.,
71 FERC ¶ 61,338 , 1995 WL 359835 (1995)
(Lakehead), reh’g denied,
75 FERC ¶ 61,181 , 1996 WL 263694 (1996)
(“Lakehead
//”), insofar as it changed the ability of limited partnerships like SFPP to include certain income tax allowances in their cost of service, represented a substantial change in SFPP’s economic circumstances. The Commission reasoned that the mere existence of the
Lakehead
policy, without any showing how the application of that policy affects the economic basis for the rates, cannot constitute substantially changed circumstances.
See
Opinion No. 435, 86 FERC 61,070 -71. In light of our conclusion below that aspects of the Commission’s
Lakehead
policy are arbitrary and capricious, we think the best course is to remand this claim to the Commission for further consideration in light of our disposition in this ease.
2,
Contractual Prohibition
The WLS next contend that they may challenge the grandfathered West Line rates because they fit within the “contractual prohibition” exception. That exception allows a shipper to challenge a grandfathered rate when “the person filing the complaint was under a contractual prohibition against the filing of a complaint which was in effect on the date of enactment of [the EPAct] and had been in effect prior to January 1, 1991.” EPAct § 1803(b)(2). Navajo, as a part of an earlier settlement with SFPP, was subject to such a prohibition and thus was permitted to file a complaint against the West Line rates without demonstrating substantially changed circumstances.
See SFPP, L.P.,
67 FERC ¶ 61,089 , 61,254, 1994 WL 141625 (1994). Navajo, however, reached another settlement with SFPP and withdrew its complaint against the pipeline.
SFPP, L.P.,
79 FERC ¶ 63,014 , 1997 WL 371129 (1997). The Commission then terminated the Navajo complaint proceeding.
SFPP, L.P.,
80 FERC ¶ 61,088 , 1997 WL 564554 (1997).
*1281
The WLS nevertheless argue that they, too, should not have to show substantially changed circumstances. First, they assert that Navajo’s invocation of the contractual prohibition exception effectively vitiated the West Line rates’ grandfathered status as to
all
complaining shippers.
See
WLS Br. 18 (“The ‘grandfathered’ status of the West Line rates ... was thus revoked.”). Alternatively, the WLS argue that because the ALJ conditioned Navajo’s “withdrawal of the complaint” on “not prejudic[ing] in any way the status and rights of any other participants in this proceeding,”
SFPP, L.P.,
79 FERC at 65,176, the other complaining shippers should be able to pursue them complaint as if Navajo had not withdrawn — that is, without showing substantially changed circumstances. The Commission rejected both of these arguments. From the first, the Commission recognized that the contractual prohibition exception is party-specific. “Because neither Chevron nor ARCO/Texaco was subject to a contractual bar [as was Navajo], it follows, under the plain meaning of the language of the statutory provision, that the complaints of Chevron and ARCO/Texaco [must show substantially changed circumstances].”
SFPP, L.P.,
68 FERC at 61,-581. As for the shippers’ claim that they had been prejudiced by Navajo’s withdrawal, the Commission concluded that the condition on Navajo’s settlement applied only to “the integrity of the record.” Opinion No. 435, 86 FERC at 61,073.
We agree with the Commission. The language of Section 1803(b)(2) is quite obviously party:specific. EPAct § 1803(b)(2)
(“the person filing the complaint
was under a contractual prohibition”) (emphasis added). An interpretation, like that suggested by the WLS, that would allow other shippers to piggyback' on the status of a contractually-prohibited shipper, conflicts not only with the plain language of the statute, but also with Section 1803’s overarching purpose of limiting litigation over pre-EPAct rates. On the other hand, the Commission’s interpretation — limiting the exception to those parties actually contractually prohibited from complaining — is entirely consistent with the statute and therefore reasonable. We also find no merit to the WLS’ claim that they were somehow prejudiced by Navajo’s settlement. After examining the relevant proceedings,
see SFPP, L.P.,
79 FERC at 65,176,.we think it clear that the ALJ, in implicitly promising that Navajo’s withdrawal would not “prejudice ... the status and rights of any other, participants in proceeding,” was referring only to the evidence that Navajo had placed into the administrative record.
II. The East Line
SFPP’s East Line rates were not grandfathered under § 1803 of the EPAct, as EPR, as an ELS, had challenged them in the same September 1992 complaint in which it had protested SFPP’s flow-reversal on the six-inch line. They were therefore “subject to protest, investigation, or complaint” within the year prior to the EPAct’s enactment. Navajo later filed its own complaint against the East Line rates, and the Commission proceeded under the ICA, which, in Section 15, empowers the Commission to set aside rates it finds “unjust or unreasonable,” and to “determine and prescribe what will be the just and reasonable ... rates, fares or charges to be thereafter observed.” 49 U.S.C. app. § 15(1) (1988). The ALJ evaluated SFPP’s East Line rates pursuant to its cost of service regulations, 18 C.F.R. § 346.2 (2004), found them unjust and unreasonable, and proceeded to set new ones in their place. ALJ Decision, 80 FERC at 65,122-191. The Commission substantially affirmed the ALJ’s determination in Opinion No. 435, 86 FERC at 61,084-111. Un
*1282
der the Commission’s rate-of-return methodology, this involved determinations of SFPP’s embedded capital costs, its yearly operating expenses, allowances for other costs, and its appropriate rate of return.
See
18 C.F.R. § 346.2 (c).
The proceedings befox-e the Commission were complex, and many of the issues it decided in setting new East Line rates (and in determining that the previous rates were unjust or unreasonable) have not been challenged. As relevant to our review, the parties dispute only four discrete issues regarding the Commission’s East Line rate-setting: (1) the starting rate base to which SFPP was entitled; (2) what tax allowance, if any, should be factored into rates; (3) the proper means of recovery, if any, of SFPP’s litigation expenses; and (4) the treatment of SFPP’s claimed expenses for reconditioning portions of the East Line.
The court reviews the Commission’s ratemaking decision to determine whether it was arbitrary and capricious,
see Association of Oil Pipelines v. FERC,
83 F.3d 1424, 1431 (D.C.Cir.1996)
(“AOPL”),
according special deference to the Commission’s expertise,
id.
at 1431 ;
see also In re Permian Basin Area Rate Cases,
390 U.S. 747, 790 , 88 S.Ct. 1344, 1372 , 20 L.Ed.2d 312 (1968). The court thus examines the Commission’s ratemak-ing decisions to determine whether the Commission has examined the relevant data and articulated a rational connection between the facts found and the choice made.
AOPL,
83 F.3d at 1431 . The Commission must “cogently explain why it has exercised its discretion in [the] given manner.”
Exxon Corp. v. FERC,
206 F.3d 47, 54 (D.C.Cir.2000) (quoting
Motor Vehicle Mfrs. Ass’n of U.S., Inc. v. State Farm Mut. Auto. Ins. Co.,
463 U.S. 29, 48-49 , 103 S.Ct. 2856, 2869-70 , 77 L.Ed.2d 443 (1983)).
A.
Starting Rate Base
The Commission decided that to measure SFPP’s overall investment upon which it is entitled to a return, SFPP should use its December 19, 1988 capital structure. Opinion No. 435-A, 86 FERC at 61,503-06. In assessing the value of a pipeline’s invested capital, the Commission’s approach — stemming from its opinion in
Williams Pipe Line Co.,
31 FERC ¶ 61,377 , 0085 WL 547106 (1985) (“Opinion No. 154-B”) — weighs equity and debt-financed capital investments made prior to 1985 differently, and SFPP contends that the Commission used the wrong historical ratio between the two in setting the starting rate base.
Some explanation of the “starting rate base” concept and its history is necessary. Prior to June 28, 1985, the rate base to be included in oil pipeline cost of service analysis was calculated under an Interstate Commerce Commission (“ICC”) valuation method, which combined elements of original and reproduction cost. In
Farmers Union Central Exchange, Inc. v. FERC,
584 F.2d 408 , 417-20 (D.C.Cir.1978)
(“Farmers
/”), the court expressed concerns about the ICC’s valuation methodology, particularly its tendency to overvalue assets so as to “exceed[ ] investment by a substantial amount.”
Id.
at 415. After the Commission proposed to continue to use the ICC’s valuation method in
Williams Pipe Line Co.,
21 FERC ¶ 61 ,-260, 1982 WL 39144 (1982), the court, on review from that decision, remanded the ease in
Farmers Union Central Exchange, Inc. v. FERC,
734 F.2d 1486 , 1510-14 (D.C.Cir.1984)
(“Farmers
II”), and directed the Commission to consider alternatives, noting the widespread agreement among many experts that the ICC’s method “lacks any economic rationale.”
Id.
at 1511 (internal citation omitted).
*1283
On remand from
Farmers II,
the Commission developed its current “trended original cost” method. Opinion No. 154-B, 31 FERC at 61,833-35. This method starts from the original cost of a pipeline’s assets but smooths out depreciation and equity recovery over the life of the pipeline, thereby avoiding the front-loading problems associated with a depreciated original cost methodology. Making the switch to this “trended original cost” method required the Commission to account for investments in existence at the time of the change. Under the ICC’s valuation rate base methodology, many of these had been valued substantially above investment cost.
See Farmers I,
584 F.2d at 415. Setting them value to depreciated original cost would, in many cases, have significantly decreased their valuation for rate-setting purposes.
See
Opinion No. 154-B, 31 FERC at 61,836. To mitigate any abrupt reduction in pipeline earnings resulting from the change, the Commission permitted a one-time rate base adjustment — creating a so-called starting rate base — calculated by partially continuing the ICC’s valuation method to the extent of a pipeline’s equity ratio, but assessing its rate base at depreciated original cost to the extent of its debt ratio. Opinion No. 154-B, 31 FERC at 61,835-37. Because the stated purpose of this approach was to protect the expectations of investors who had invested prior to the switch, the Commission determined that the relevant debt-to-equity ratio would be a pipeline’s capital structure as of the date of Opinion 154-B, June 28,1985, rather than its capital structure at the time rates are set.
See Williams Pipe Line Co.,
33 FERC ¶ 61 ,-327, 61,640, 1985 WL 66487 (1985) (“Opinion No. 154-C”).
The court has never reviewed the reasonableness of the Commission’s Opinion No. 154-B methodology, nor need we do so now, as no party has challenged whether that approach is faithful to the court’s remand order in
Farmers II,
734 F.2d at 1511-21. The ELS support the Commission’s application of the Opinion No. 154-B methodology, and SFPP contends only that the Commission’s use of December 19, 1988 rather'than June 28, 1985 as the relevant snapshot of the pipeline’s capital structure is not faithful to Opinion No. 154-B and its progeny. We turn, then, to SFPP’s contention that the Commission acted arbitrarily and capriciously, and departed from past precedent without adequate explanation, in rejecting use of the actual June 28, 1985 capital structure of the Santa Fe Southern Pacific corporation (“SFSP”), the pipeline’s then-parent.
SFPP did not yet exist in 1985, and its predecessor corporation, Southern Pacific Pipelines, Inc. (“SPPL”), was a wholly-owned corporate subsidiary of SFSP. SPPL therefore had a 100% equity structure, and no party urged the Commission to use that capital structure to calculate SFPP’s starting rate base. SPPL’s parent, SFSP, was capitalized at 78.29% equity and 21.71% debt at the time, and SFPP urged the Commission to follow Opinion No. 154-B’s instruction to use the parent’s capital structure to calculate the starting rate base. Initially, in Opinion No. 435, 86 FERC at 61,089-90, the Commission took the position that the 1988 settlement agreement between SPPL and several of its shippers, which had last set the pipeline’s rates, required the use of SFSP’s capital structure in the starting rate base. On rehearing in Opinion No. 435-A, however, the Commission decided that the settlement did not preclude it from independently examining SFPP’s capital structure after the rates set by the settlement expired. The Commission determined that SFSP’s capital structure should not be used in the starting rate base calculation because SFSP’s high equity component in
*1284
June 28, 1985 did not “accurately reflect! ] the risks of SFPP’s underlying operations,” and there was a “significant difference in the nature of the pipeline’s operations and those of its parent company on June 28, 1985.” Opinion No. 435-A, 91 FERC at 61,504-05.
SFPP contends that Opinion No. 154-B requires, in cases where a pipeline is owned by a parent company and therefore does not issue debt in its own name, the use of a parent company’s capital structure as of June 28, 1985. Opinion No. 154-C, which clarified Opinion No. 154-B, does contain the instruction that “the capital structure to be used in determining the starting rate base is as of the date of Opinion No. 154-B (June 28, 1985).” 33 FERC at 61,640. The Commission qualified that approach, however, in
ARCO Pipe Line Co.,
52 FERC ¶ 61,055 , 61,233-34, 1990 WL 317731 (1990), where it began applying its precedents from the rate-of-return context — in which it first examines whether a parent company’s capital structure is representative of its subsidiary’s risk level before imputing it to the subsidiary — to the capital structure used in the starting rate base calculation. While the Commission in
ARCO
ended up using the corporate parent’s actual capital structure, it indicated that its decision to do so hinged on “whether the capital structure is representative of the pipeline’s risks.”
Id.
at 61,233 .
ARCO
did not contain much by way of explanation about why the representativeness of a parent’s capital structure to the pipeline’s risks should matter; its relevance to the starting rate base, where the equity component is standing in as a measure of investor reliance on the old ICC valuation method, appears less obvious than in the rate-of-return context, where pipelines receive different returns on debt and equity to compensate for their different risk levels,
see, e.g., Kuparuk Transportation Co.,
55 FERC ¶ 61,122 , 61,375-78, 1991 WL 518187 (1991);
Alabama-Tennessee Natural Gas Co.,
25 FERC ¶ 61,151 , 61,417-18 (1983). But the Commission’s basic premise that a capital structure representative of a pipeline’s risks must be used in the starting rate base calculation is not at issue, for SFPP concedes that the Commission can depart from a parent’s actual capital structure if it is “not ... representative of the pipeline’s risks.” SFPP Pet. Br. 17. SFPP’s challenge goes only to whether the Commission made a reasoned decision applying that standard, and nothing about the Commission’s determination of SFPP’s, SPPL’s, and SFSP’s relative risk levels was arbitrary or capricious.
The Commission noted that the bulk of SFSP’s business was in the railroad, trucking, and mineral exploration industries, which faced substantially higher amounts of competition than the pipeline, a regulated “monopoly for the entire period” guaranteed a fair rate of return and “sufficiently secure that it proposed to undertake a major expansion beginning in 1985.” Opinion No. 435-B, 96 FERC at 62,067. Most importantly, the Commission had a powerful piece of evidence of the pipeline’s relatively low risk level: its initial public offering. When it first became a standalone entity on December 19, 1988, SFPP was able to adopt a capital structure financed with 60.74% debt and 39.26% equity. This strongly suggests a market judgment that the pipeline was significantly less risky than SFSP, which was financed with 78.29% equity and 21.71% debt. The Commission’s view that SFPP’s equity level as of its initial public offering more “accurately reflect[ed] the pipeline’s risk” than that of its previous parent was based upon a reasoned view that “the financial market’s perceptions of the pipeline’s risk,” as demonstrated through an “arms
*1285
length public offering,” provide an accurate estimate of an entity’s risk level. 96 FERC at 62,068. SFPP misses the mark when it states that there is no single capital structure dictated by the market, for although other reasonable debt-equity ratios might have been adopted for SFPP, none would have market imprimatur. The reasonableness of the Commission’s position is confirmed by the very different nature of the respective entities’ business operations and the stark contrast between the capital structures each adopted. The same reasoning explains the Commission’s choice to use December 19, 1988, the date of SFPP’s initial public offering, as the relevant snapshot of its equity level, hardly an arbitrary date given its reliance on the judgment of the financial markets.
SFPP maintains, however, that by adopting SFPP’s December 19, 1988 capital structure for purposes of the starting rate base calculation, the Commission improperly applied it “retroactively,” thereby denying the pipeline a fair chance to bring itself in line with the capital structure hypothesized. The Commission’s use of the December 19, 1988 capital structure was predicated on the conclusion that it was representative of the pipeline’s risks in 1988, and that there were “no rational grounds here to believe that SPPL’s operations or business substantially changed between June 28, 1985 and December 19, 1988.” Opinion No. 435-B, 96 FERC at 62,067. SFPP points to nothing that suggests otherwise. The starting rate base is an element of the determination of the prospective rates “in dispute in this proceeding,” and the Commission was neither altering past rates nor seeking to recover the pipeline’s past losses in future rates; rather, it was determining a just and reasonable valuation of the pipeline’s investment for the purpose of setting present rates. As such, there was nothing “retroactive” about the Commission’s setting of the starting rate base.
Because the record contained sufficient evidence on which the Commission could find that SPPL faced significantly lower risks than SFSP in 1985, and SFPP concedes that the Commission may depart from an actual capital structure in the starting rate base formula where it is not representative of a pipeline’s risks, the court has no occasion to decide whether the Commission improperly relied on non-record material from Moody’s Transportation Manual regarding the poor financial condition of the Southern Pacific Railroad during the relevant period. Nor need we decide whether the Commission’s other basis for departing from SFSP’s 1985 capital structure — its concern that SFSP’s 78.29% equity component would yield an exorbitantly high starting rate base — would suffice to uphold its decision. Accordingly, we affirm the Commission’s starting rate base decision.
B.
Cost Issues
1.
Income Tax Allowance
As one element of the cost of service allowable to SFPP, FERC included a 42.7% income tax allowance reflecting the interest in the regulated entity held by a subchapter C corporation. All petitioners assigned this tax allowance as error. The shipper petitioners, and intervenors supporting them, allege as error the recognition of any income tax allowance as SFPP is a limited partnership that pays no income taxes. SFPP alleges as error the denial of a full income tax allowance. Because FERC has not established that its 42.7% allowance is the product of reasoned decisionmaking and indeed has provided no rational basis for this part of its order, we find that allowance to have been erroneous and we vacate.
*1286
There is no question that as a general proposition a pipeline that pays income taxes is entitled to recover the costs of the taxes paid from its ratepayers. We explained this proposition thoroughly in
City of Charlottesville v. FERC,
774 F.2d 1205 (D.C.Cir.1985) (Scalia, J.). While we will not fully discuss the analysis set forth in that decision, we will briefly review the basic principles as background for the current controversy.
The Commission must ensure that the rates of jurisdictional pipelines are “just and reasonable.”
Id.
at 1207 (quoting 15 U.S.C. § 717c(a) (1982)). This means that using the principles of cost of service rate-making, Commission-approved rates must yield “sufficient revenue to cover all proper costs,” and provide an appropriate return on capital.
Id.
(citing
Pub. Serv. Co. of New Mexico v. FERC,
653 F.2d 681, 683 (D.C.Cir.1981)). Taxes, including federal income taxes, are costs.
See id.
at 1207. The difficulty in the application of this seemingly straightforward principle arises when “the utility is part of a consolidated group,” only a portion of which is regulated.
Id.
Historically, the Commission has employed two differing methodologies for attribution of tax costs in dealing with this difficulty. Again,
City of Charlottesville
provides the background for understanding the two methodologies. Under the older, “flow-through” methodology, the Commission “derive[d] an effective tax rate by determining the ratio of each [regulated] pipeline’s taxable income to the total taxable income of all affiliates, multiplied] this fraction by the group’s consolidated tax liability, and divide[d] this figure by the pipeline’s taxable income.”
Id.
at 1207 . Under the more recently derived “stand-alone” methodology, the Commission has sought to segregate the regulated utility, then determine “the taxable income and deductions ... specifically attributable to the utility’s jurisdictional activities.”
Id.
Under this approach, the Commission then applies “the statutory tax rate ... to the tax base to yield the stand-alone tax allowance.”
Id.
The present controversy arises from the fact that neither of these historic methods can by its terms be literally applied to the rates of SFPP.
The name of the jurisdictional pipeline operator explains the origin of the difficulty. SFPP, L.P., is a limited partnership — specifically a publicly-traded one. Both the flow-through and stand-alone methodologies presume taxable income generated by the regulated entity. Each arose in the context of corporate ownership of a jurisdictional pipeline by a taxpaying corporation which is part of an affiliated group. Shipper petitioners concede that were SFPP a subchapter C corporation, a tax allowance would be appropriate in order “to insure that the regulated entity has the opportunity to earn its allowed return on equity.”
Lakehead,
71 FERC at 62,314. But a limited partnership operating jurisdictional pipelines incurs no income tax liability. 26 U.S.C. § 7704 (d)(1)(E). Therefore, shipper petitioners contend there is no rational basis for FERC to approve an income tax allowance for a limited partnership that incurs no income taxes. Thus, shippers argue, FERC erred in allowing even a 42.7% tax allowance in the rates of SFPP.
Shippers raised this argument before the Commission and the Commission discussed it in Opinion No. 435.
See
86 FERC at 61,101-07;
see also
Opinion No. 435-A, 91 FERC at 61,508-09; Opinion No. 435-B, 96 FERC at 62,077-78. In ah of its iterations, FERC’s discussion of the issue has been in terms of the
“Lakehead
policy.” FERC first announced that policy in
Lakehead,
71 FERC ¶ 61,338 , and offered certain clarifications of the policy in
Lakehead II,
75 FERC ¶ 61,181 . That
*1287
case also involved ratemaking of a limited partnership. In
Lakehead ,
the Commission declared that where a regulated pipeline is a non-taxed limited partnership, it will not be permitted the same tax allowance as it would if the pipeline company were a corporation. However, FERC further ruled that where the limited partnership includes corporate partners, it would treat the partnership as being “in essence a division of each of its corporate partners” for purposes of determining an income tax component in the partnership’s cost of service computation.
Lakehead,
71 FERC at 62,315. Importantly, FERC’s opinion in
Lakehead
was never subjected to judicial review, and neither this court nor any other circuit has ever passed on the validity of the
Lakehead
policy. Therefore, while FERC may deem itself bound to follow that policy, we are not so bound and consider its validity for the first time in this application. All petitioners urge us to reject it in whole or in part, though for differing reasons.
Commencing with the assumption that it should apply the
Lakehead
policy to SFPP’s ratemaking, FERC considered the question before it to be the determination of how that policy applied to a limited partnership composed of one partner (or partners) that is a subchapter C (taxpaying) corporation and other partners that are not subchapter C corporations but rather individuals, subchapter S corporations, trusts, or other entities that do not incur corporate income tax. FERC’s analysis is rooted in the rationale offered in
Lakehead ,
discussed in the ALJ Decision,
see
80 FERC at 65,179, and adopted by the Commission in Opinion No. 435,
see
86 FERC at 61,102. The Commission bases that rationale on the “double taxation” incurred in the context of subchapter C corporations, in which the profitmaking corporation is liable for corporate income tax and the shareholders of the corporation are individually liable for their individual income tax on dividends generated by the profitmaking corporations.
5
The Commission in
Lakehead
ruled that “because the corporate tax is an extra layer of taxation, the Commission includes an element for the corporate taxes in the cost-of-service to insure that the regulated entity has the opportunity to earn its allowed return on equity.” 71 FERC at 62,314. This same rationale guided the Commission’s computation of tax allowance for the nontaxpay-ing limited partnership, including one or more subchapter C partners, throughout the
Lakehead
administrative litigation and the SFPP ratemaking now before us. Because SFPP, Inc., a subchapter C corporation, held a 42.7% interest
6
in the SFPP limited partnership, the Commission included in the cost of service computation for SFPP, L.P., a 42.7% allowance for income taxes that would have been incurred had the pipeline’s jurisdictional earnings been subject to corporate taxation. 86 FERC at 61,103.
Shippers contend that FERC erred in including this income tax allowance, arguing that the ALJ was correct that because no income taxes have been or will be paid on SFPP’s partnership income, the inclusion of an income tax allowance in the cost of service constitutes allowance for “phantom taxes.”
Id.
SFPP, on the other hand, contends that the 42.7% allowance is in
*1288
fact inadequate to reflect cost of service. It argues that the
Lakehead
policy results in an understatement of the appropriate income tax allowance, and that the Commission should have applied a version of the “stand-alone” methodology discussed above, treating the regulated entity as if it alone were responsible for taxes which would have been incurred on the same income had the jurisdictional pipeline been a taxable corporation.
Because we conclude that FERC’s rationale does not support its conclusion, we hold that inclusion of the 42.7% income tax allowance in the cost of service computation was erroneous and we vacate FERC’s order to that effect. We further conclude that SFPP’s arguments are not well-taken and reject the proposition that FERC should have included the 100% allowance that SFPP seeks. We further conclude that the shipper petitioners offer a convincing analysis consistent with ratemak-ing principles and governing law, and that on the record before us SFPP is entitled to no allowance for the phantom income taxes it did not pay.
We cannot conclude that FERC’s inclusion of the income tax allowance in SFPP’s rates is the product of reasoned decision-making. In
Lakehead ,
as re-adopted in the opinion before us, the “reasoning” consists of a recitation of separately unassailable statements that do not together constitute a syllogism leading to the conclusion purportedly based on them. The Commission in
Lakehead
reasoned that:
1. Under cost-of-service ratemaking principles a regulated company is entitled to rates that yield sufficient revenue to cover its appropriate costs.
2. Income tax allowance is no different from the allowance for any other costs.
3. When the regulated entity is organized as a corporation, its revenues are taxed at the corporate tax rate and the earnings of the owners (shareholders) of the corporation are then taxed on dividends at their particular rate.
71 FERC at 62,314.
To that point the Commission’s statements are unassailable. However, the Commission follows these statements with a rather cryptic statement. “Because the corporate tax is an extra layer of taxation, the Commission includes an element for the corporate taxes in the cost-of-service to ensure that the regulated entity has the opportunity to earn its allowed return on equity. However, there is no allowance for the taxes paid by the owners of the corporation.”
Id.
Again, the second of these two sentences is inarguable, but it is not at all clear what the Commission means by the first. It would seem to follow from the Commission’s own reasoning in the preceding elements of analysis, as well as fundamental principles of rate-making, that if the corporate tax is to be included in the cost-of-service, it is not because it is “an extra layer of taxation,” but rather because it is a
cost. Id.
In the Commission’s own words, a tax allowance is “no different from the allowance for any other costs.”
Id.
Presumably whatever tax rate was applicable to a tax-paying regulated entity would be included in the cost-of-service analysis, nor does anything said by the Commission in
Lakehead
or in the opinions before us dispute that presumption. From this line of “reasoning,” FERC proceeded to conclude that the limited partnership operating a jurisdictional pipeline “is entitled to an income tax allowance with respect to income attributable to its corporate partners.”
Id.
The only further explanation that FERC offers for this conclusion is “when partnership interests are held by corporations, the partnership is entitled to a tax allowance in its cost-of-service for those corporate interests because the tax costs will be passed
*1289
on to the corporate owners who must pay corporate income taxes on their allocated share of income directly on their tax returns.”
Id.
The Commission then goes on to “conclude[ ] that [the limited partnership pipeline] should not receive an income tax allowance with respect to income attributable to the limited partnership interests held by individuals ... because those individuals do not pay a corporate income tax.”
Id.
at 62,315 . Presumably, however, the individual owners pay individual income taxes. Also, presumably many owners (shareholders) of corporate holders of limited partnership interests will not be paying taxes on dividends as corporations often do not generate dividends.
7
In the original
Lakehead
opinion, the Commission had little further to say about why it distinguished between the corporate taxes of corporate unit holders and the individual income taxes of individual unit holders. In
Lakehead II ,
and in the opinions we review today, the Commission did offer some attempt to explain the distinction.
In
Lakehead II ,
FERC considered the argument of the
Lakehead
limited partnership that the Commission’s refusal to grant a tax allowance reflecting the tax liabilities of all limited partnership unit holders, whether or not each holder was a subchap-ter C corporation, did not comport with the Commission’s own “actual taxes paid” rationale, because the Commission, under the “stand-alone” tax policy discussed above, would permit “a regulated entity to collect a fair tax allowance even where no actual tax liability is incurred.”
Lakehead II,
75 FERC at 61,594.
Lakehead II
went on to argue that under this rationale, even if the jurisdictional entity is a non-taxed limited partnership, “rate payers should be responsible for the tax liability otherwise associated with the revenue generated from the jurisdictional activities, without regard to any actual amount paid to the IRS.”
Id.
In rejecting the argument, the Commission stated, no doubt correctly, that in the case of a jurisdictional corporate subsidiary of a corporate group, “the allowed equity return generates an actual tax liability for the pipeline that must be paid to the IRS, either in cash or through the use of another member’s deductions .... [E]ither way, the tax liability of the jurisdictional company is a real cost of providing service.”
Id.
at 61 ,595 (citing
Northern Border Pipeline Co.,
67 FERC ¶ 61,194 , 61,110-11, 1994 WL 196221 (1994)). As applied to tax liability generating corporate subsidiaries engaged in jurisdictional activities, the Commission’s statement is again quite defensible, when such a subsidiary does not itself incur a tax liability but generates one that might appear on a consolidated return of the corporate group. The difficulty arose when the Commission attempted to take the next step and explain why this reasoning applied to an entity that is a nontaxable limited partnership and to justify discriminating between allowances for the tax liability of corporate unit holders and the tax liability of those unit holders who are individuals or otherwise not subchap-ter C corporations. The Commission’s reasoning on that point extends for two more paragraphs, but is summarized in the following statement immediately following the last quoted language from
Lakehead IP.
In contrast, there is no corporate tax liability associated with individual partners’ equity return and therefore it is
*1290
not appropriate to allow Lakehead to collect for such amounts in its cost-of-service.
Id.
This does not supply reasoning for differentiating between individual and corporate tax liability. It is merely restating the proposition that the Commission is so differentiating. Otherwise stated, the Commission is once again simply declaring: we are including a tax allowance for corporate tax liability; we are not allowing a deduction for individual income tax liability. To re-phrase a proposition is not the same as supplying supporting reasoning. In short, the Commission’s opinions in
Lakehead
do not evidence reasoned deci-sionmaking for their inclusion in cost of service of corporate tax allowances for corporate unit holders, but denial of individual tax allowances reflecting the liability of individual unit holders.
Nonetheless, we could sustain the Commission’s decision if the opinions we review had added the reasoned decisionmaking lacking in
Lakehead .
They do not. Before the court, the Commission’s counsel argues that the distinction is justified in the reasoning offered by the ALJ in the portion of his decision affirmed by the Commission. The ALJ, attempting to apply the
Lakehead
policy, had reasoned that “investors in a regulated pipeline are entitled to a return ‘commensurate with returns on investments in other enterprises having corresponding risk.’ ” ALJ Decision, 80 FERC at 65,177 (quoting
FPC v. Hope Natural Gas Co.,
320 U.S. 591, 603 , 64 S.Ct. 281, 288 , 88 L.Ed. 333 (1944)). Still struggling with the
Lakehead
policy which had permitted a corporate income tax allowance but not an allowance for the tax liability of other investors in the limited partnership, the ALJ concluded “because there is no dual taxation, a tax allowance is not necessary to ensure that an individual limited partner obtains a ‘commensurate return.’ ”
Id.
We agree that the ALJ’s invocation of the
Hope Natural Gas Co.
principle was apt, but unlike the Commission, we agree that the conclusion he based it on was sound.
The
Hope Natural Gas
decision did not itself involve attribution of tax liability for purposes of determining allowances and ratemaking. It did however, apply general principles of ratemaking that are instructive in that context. As the Commission argues to us, that decision teaches that the Commission’s ratemaking function involves “a pragmatic assessment of whether the rates prescribed for a pipeline will support its services and provide a reasonable return to its investors.” FERC Br. 60 (citing
Hope Natural Gas,
320 U.S. at 602 , 64 S.Ct. at 287-88 ;
Farmers II,
734 F.2d at 1502). However, the Commission’s premise again does not lead to the Commission’s conclusion. The ALJ correctly derived from
Hope Natural Gas
the more specific principle that the regulating commission is to set rates in such a fashion that the regulated entity yields returns for its investors commensurate with returns expected from an enterprise of like risks. Were the corporate unit holders investing in a non-regulated entity of like risk and otherwise similar return, they would of course expect to pay their own corporate tax on any profit they might realize from that investment. Should that profit generate dividends from the corporations, the shareholders would expect to pay their own taxes on such dividends.
8
Likewise, individual investors in such a non-regulated enterprise would expect to pay their individual taxes thereon. Granted, the second group of investors would pay one level of taxation; the first group, at least potentially, two layers of taxation.
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This is a product of the corporate form, not of the regulated or unregulated nature of the pipeline or any comparable investment or of the risks involved therein. Therefore, consistent with
Hope Natural Gas,
the ALJ correctly concluded that where there is no tax generated by the regulated entity, either standing alone or as part of a consolidated corporate group, the regulator cannot create a phantom tax in order to create an allowance to pass through to the rate payer. The Commission erred when it rejected the ALJ’s conclusion.
As we have recited repeatedly above, and as the Commission itself has recognized in this very proceeding, under cost-of-service principles, a regulated company is entitled to a rate design to yield sufficient revenue to cover its appropriate cost,* income tax allowance is no different from the allowance of any other costs. The regulated pipeline generates many costs, for example bookkeeping expenses. Presumably those bookkeeping expenses are recoverable in its rates. Its corporate unit holders, if any, presumably also have bookkeeping expenses. The bookkeeping expenses of the corporate unit holders are not recoverable in the rates of the pipeline, even though the corporation and its shareholders each may independently be paying bookkeepers and accountants unlike individual unit holders who pay only for their own accounting. All of this makes sense. It makes equal sense when applied to income taxes.
SFPP, while raising its own objections to the
Lakehead
policy, joins the Commission in opposing the shipper petitioners’ arguments that no income tax allowance should be included in the ratemaking. SFPP, however, argues that the Commission not only did not err in including the potential tax liability of its corporate unit holders, it instead erred in not including the potential tax liability of its individual or other non-subchapter C corporate unit holders. That argument serves to illustrate further why the ALJ was correct in including no such pass-through or phantom taxes at all. Under the Commission’s present order, the imputed tax liability of the corporate unit holders creates an allowance included in the making of the rate for the pipeline. The ratepayers pay that rate for the product shipped, but the allocation of the nontaxed profit of the limited partnership pipeline is, so far as the record reflects, subject to division among the unit holders rateably according to their interest in the limited partnership, not affected by how their share of the profits will ultimately be taxed. Therefore, even if the Commission’s goal of changing the risk analysis of “double-taxed” investors were a valid one, it is not being accomplished. The inclusion of the phantom taxes in the rate changes the profit margin for all unit holders in the untaxed limited partnership, not just those who are under a particular tax structure. Therefore, SFPP may well be correct that if such an allowance were allowable at all, it should have been allowed for the imputed taxes potentially incurred by all unit holders who realized taxable income from the untaxed profits of the limited partnership of the pipeline. For the reasons set forth above, we hold that the first step of this analysis is erroneous — that is, we hold that no such allowance should be included.
Both FERC and SFPP argue that the position we adopt today is inconsistent with the “stand-alone” methodology approved by this court in
City of Charlottes-ville,
for reasons related to the so-called “actual tax” principle discussed therein.
City of Charlottesville,
774 F.2d at 1207, 1215 . Again, we will not rehash the full analysis of
City of Charlottesville ,
but simply will remind SFPP that the stand-alone principle as approved in
City of Charlottes-
*1292
ville
dealt with the imputation of taxes within a corporate structure where the imputation was made necessary not by the non-taxable, non-corporate nature of the regulated entity, but by the allocation of profits and losses among the related members maintaining separate balance sheets within a consolidated corporate group. While it is true that then-Judge Scalia posited the applicability of the stand-alone methodology to a circumstance in which taxes were “not necessarily ... paid,”
id.
at 1215 , that analysis dealt with the use of “actual or estimated taxes paid or incurred” rather than being limited to actual taxes paid. But the part of the
City of Charlottesville
opinion in which that discussion occurred dealt with the argument that the taxes, though properly estimated and actually incurred, might not ever be actually paid because of such factors as losses generated in the corporate structure, or the allocation of profits between and among taxable years in such a fashion as to result in a different tax actually being paid, if any at all.
See id.
at 1214-15 . Nothing in the
City of Charlottesville
opinion suggests that it is the business of the Commission to create tax liability when neither an actual nor estimated tax is ever going to be paid or incurred on the income of the utility in the ratemaking proceeding.
9
Finally, SFPP argues that adopting the
Lakehead
policy and applying it to this case to restrict the allowance to the taxes of the corporate unit holders as opposed to imputing the taxes of all unit holders “runs directly contrary to legislation in which Congress expressly sought to encourage the publicly traded partnership formed for oil pipelines and other selected industries.” Underlying this argument is Congress’s 1987 enactment of Section 7704 of the Internal Revenue Code. 26 U.S.C. § 7704 (added by Pub. L. 100-203, Title X, § 10211(a), Dec. 22, 1987, 101 Stat. 1330 -403). Under Section 7704, Congress decreed that, in general, publicly traded limited partnerships would be taxed as corporations. However, Congress made the policy decision that for a limited number of industries, including “pipelines transporting gas, oil, or products thereof,” limited partnerships should operate without taxation to encourage investment in those critical industries.
Id.
§ 7704(d)(1)(E). SFPP argues that because Congress singled out a narrow category of enterprises with the intent to facilitate investment in such enterprises by providing a tax-efficient means to raise capital, FERC’s policy is inconsistent with congressional intent because it provides a smaller incentive than would be the case if it granted an allowance for phantom taxes based on all unit holders instead of simply the corporate ones. This is a classic case of an argument proving too much.
SFPP’s argument would equally, apply to any decision by the Commission that caused the pipeline lower allowances rather than higher. Unsurprisingly, SFPP is able to offer no precedent for the proposition that we should compel the Commission, or any other agency, to adopt a rate structure bringing it into line with the perceived intent of Congress to achieve objectives in general, as opposed to consistency with the mandate adopted by Con
*1293
gress in furtherance of such objectives. As we have noted in other contexts, congressional mandates to agencies to carryout “specific statutory direetive[s] define[ ] the relevant functions of [the agency] in a particular area.”
Michigan v. EPA,
268 F.3d 1075, 1084 (D.C.Cir.2001). Such a mandate does not create for the agency “a roving commission” to achieve those or “any other laudable goal.”
Id.
The mandate of Congress in the tax amendment was exhausted when the pipeline limited partnership was exempted from corporate taxation. It did not empower FERC to do anything, let alone to create an allowance for fictitious taxes.
For the reasons set forth above, we vacate the tax-allowance portion of the FERC opinion and order allowing recovery for income taxes not incurred and not paid.
2.
Litigation Costs
This case has been an expensive one. At the time of the ALJ Decision, 80 FERC ¶ 63,013 , SFPP sought to recover $15.1 million for litigation expenses and associated costs related to Commission and certain civil litigation. This included a $12 million litigation expenses reserve plus $3.1 million that SFPP claimed was a direct expense associated with this rate proceeding and related civil litigation. By the time this case reached its second rehearing in 2001, Opinion No. 435-B, SFPP’s actual costs appear to have ballooned much higher; the pipeline’s 2002 compliance filing places its cumulative costs litigating this rate proceeding, as well as litigating and settling related civil litigation, at over $48.1 million.
a.
Rate Litigation
In keeping with
Iroquois Gas Transmission Sys. v. FERC, 145
F.3d 398 (D.C.Cir.1998), and its own precedents, the Commission considered SFPP’s rate litigation to be “part of its normal, ongoing operations” and allowed SFPP to recover these costs from shippers. It did not, however, permit recovery through a permanent rate increase. Reasoning that SFPP’s regulatory litigation costs, if “in-elud[ed] in embedded rates,” would “artificially inflate the level of rates between rate cases,” because the rate proceeding that caused most of the costs was now over and was not likely soon to recur, the Commission refused to factor them into SFPP’s indexed rates. Instead, the Commission allowed SFPP to recover its actual regulatory litigation costs in the form of an amortized five-year surcharge, with recovery of costs incurred after the 1994 test year offset by the amount which SFPP had collected in excess of the just and reasonable rates from shippers that did not file complaints within the appropriate period. The court reviews, therefore, two distinct decisions of the Commission: to use a temporary surcharge in lieu of a rate increase to recover SFPP’s rate litigation costs, and to offset the post-1994 surcharge by the amount of reparations that would have been due non-complaining shippers.
No party challenges the Commission’s decision that SFPP’s rate litigation costs are recoverable. This does not mean, however, that SFPP was automatically entitled to have those expenses treated as part of its indexed rates, as if the unusually high costs it incurred in this proceeding would regularly recur until the next rate proceeding. SFPP contends that it was entitled to have a litigation reserve factored into its cost of service, because it incurred significant regulatory litigation expenses in the test year, 1994, and was bound to continue to incur costs litigating matters before the Commission in the future. Yet nothing in the record suggests
*1294
that any other matters SFPP has pending before the Commission will generate costs close to those in this rate proceeding. A glance at SFPP’s compliance filing confirms that its litigation expenses have dropped significantly from the levels they reached between 1994 and 1997. The Commission’s reasoning for denying the rate increase, that there was “no assurance that SFPP’s litigation costs would exceed $2,914,114 a year for the several years that the 1994 rates are likely to remain in effect,” Opinion No. 435-B, 96 FERC at 62,075, seems quite reasonable. The Commission has not denied all recovery of these costs but simply limited SFPP’s recovery to its actual costs defending this proceeding and required that those costs be removed from rates once they were repaid.
Where the Commission took a more novel approach was in how it implemented this surcharge. While SFPP was permitted to recover its 1993 and 1994 regulatory litigation costs in full, the Commission offset the surcharge for later years by the amount SFPP had collected, in excess of rates ultimately set by the Commission, from shippers that did not challenge the rates and were therefore not entitled to reparations. SFPP contends that this novel approach of deducting “unclaimed reparations” from the surcharge deprived it of a full recovery, because, in effect, it recovered nothing at all for litigation costs incurred after the test year.
Although the Commission does not cite any precedent for this offset, the apparent novelty of this approach does not render it unreasonable. As the Commission noted, the costs of this proceeding were “high for all parties,” and the issue is “how those costs can be most equitably allocated.”
Id.
at 62,074. In setting prospective rates, the Commission could reasonably conclude that because SFPP had reaped a windfall by charging rates in excess of those ultimately deemed just and reasonable in the same past years for which it was claiming supplemental expenses above those it would prospectively incur as part of its cost of service, it should be required to first fund its litigation expenses out of that pool before it could begin charging those costs to its customers anew. While SFPP contends that this unfairly benefits shippers that sat on their rights by not filing complaints against SFPP’s rates, and that Section 16 of the ICA only authorizes reparations for shippers who have filed such challenges,
see
49 U.S.C. app. § 16(1) (1988), it presents no justification for being entitled to keep this windfall. The court therefore affirms the Commission’s surcharge mechanism and its corresponding offset, subject to the qualification that, depending on what rates ultimately result from this proceeding on remand, the surcharge might require recalculation.
b.
Civil Litigation Expenses
SFPP also challenges the Commission’s decision to disallow recovery in the East Line rates of significant expenses SFPP incurred in civil litigation defending its reversal of flow on a segment of six-inch pipe running between Phoenix and Tucson. SFPP’s flow reversal removed capacity from the East Line in order to allocate it to the West Line. While this benefitted West Line shippers, it would be, as the Commission recognized, inequitable to include these costs in the East Line rates, for “there appears no reason why ratepayers should bear the expense of defending conduct that had no
ex ante
prospect of benefitting them.”
See Iroquois Gas,
145 F.3d at 401 ;
see also Mountain States Telephone & Telegraph Co. v. FCC,
939 F.2d 1035, 1043 (D.C.Cir.1991)
(“Mountain States
/”). The Commission’s recognition that litigation of this sort lacks the requisite nexus to the provision of
*1295
SFPP’s East Line service to justify inclusion in those rates was not unreasonable.
SFPP was embroiled in lengthy litigation in Arizona and Texas state courts with EPR and Navajo, two East Line shippers, regarding SFPP’s reversal of flow on the six-inch line, one of SFPP’s two pipes running between Phoenix and Tucson. That litigation ultimately cost SFPP, according to its 2002 compliance filing, over $23.7 million. SFPP also has an eight-inch pipe running between the two cities. The six-inch line had been in West Line service from 1989 to 1991. When SFPP undertook an expansion of the eight-inch line (which had been in East Line service) SFPP temporarily assigned the six-inch line to the East Line. Upon completion of the expansion project, SFPP entered- an agreement with ARCO, a West Line shipper, to return the six-inch line .to West Line service, thus restoring West Line service to Tucson. EPR and Navajo sued to enjoin the reversal, alleging that SFPP had contractually agreed to provide them the extra capacity, that they had engaged in costly investments in reliance on those agreements, and that the line reversal was motivated by a desire to drive the two shippers out of business. As noted, EPR also filed a complaint with the Commission challenging both the flow reversal and SFPP’s East Line rates, thereby initiating this rate proceeding. The ALJ dismissed the portion of EPR’s complaint dealing with the flow reversal for lack of jurisdiction, noting that because the Commission has no jurisdiction to prevent SFPP from abandoning service on the six-inch line, it also lacks authority to adjudicate allocation disputes as between shippers serving different markets along the line. ALJ Decision, 80 FERC at 65,161-64. No party has sought review of that ruling. The litigation then proceeded in other courts with SFPP ultimately entering into settlements with both shippers.
The ELS’ lawsuit based on SFPP’s reallocation of capacity from the East Line to the West Line, and the corresponding litigation costs incurred by SFPP, while caused, in the immediate sense, by ELS, were not costs of East Line service or expenditures benefitting the SFPP system generally. They were costs, if anything, of making capacity available to the West Line at the East Line’s expense. SFPP did not seek to recover its costs from West Line shippers, either in the cost of service or by capitalizing them into the rate base, presumably because of the Commission’s earlier ruling that the West Line rates were grandfathered under Section 1803 of the EPAct, and therefore not subject to increase in this proceeding. Instead, SFPP sought to recover them from East Line shippers.
The Commission rejected this attempt, concluding that SFPP’s costs in settling these matters “arose out of litigation unique to the conditions of [EPR and Navajo],” and, as such, were not costs that related to the provision of East Line service as a whole. Opinion No. 435, 86 FERC at 61,106. On rehearing, the Commission ruled that the costs of litigating these matters were not recoverable, because “civil litigation of this type” involving “assertions of anti-competitive behavior and breach of contract to make capacity available” does not “address legal costs and remedies that SFPP would normally incur in the conduct of its common carrier operations.” Opinion No. 435-A, 91 FERC at 61,513. Therefore, the Commission concluded, SFPP’s litigation expenses were “extraordinary.”
Id.
On further rehearing, the Commission reaffirmed its ruling that SFPP could not recover such litigation costs in its rates. Opinion No. 435-B, 96 FERC at 62,070.
Under the Commission’s accounting regulations, extraordinary costs are defined as
*1296
costs that “possess a high degree of abnormality and [are] of a type clearly unrelated to, or only incidentally related to the ordinary and typical activities of the entity” and are “not reasonably expected to recur in the in the foreseeable future,” 18 C.F.R. pt. 352, General Instructions, l-6(a). SFPP’s flow reversal was not itself unique, for it had changed the direction of flow on the six-inch line a year before during the expansion of the eight-inch line. Nevertheless, as none of these prior reversals had generated legal disputes of this scope, the Commission could reasonably conclude that this type of.civil litigation, “an action that would not arise in .the normal course of the pipeline’s operations,” was not likely to recur. Opinion No. 435-B, 96 FERC at 62,070.
The remaining question is whether the Commission used the correct standard in determining that these costs were “clearly unrelated to, or only incidentally related to the ordinary and typical activities of the entity.” SFPP contends that any reading of this portion of the Commission’s regulations must comply with
Iroquois Gas,
145 F.3d 398 , and
Mountain States I,
939 F.2d at 1034 , particularly the latter decision’s admonition that “[i]f expenses are properly incurred, they must be allowed as part of the composition of rates. Otherwise, the so-called allowance of a return upon the investment, being an amount over and above the expenses, would be a farce.”
Id.
at 1029 (internal citations omitted).
SFPP’s position that capacity allocation litigation is an inevitable cost of doing business with two shipper camps competing for the same markets is not without some persuasiveness. The court has generally taken a somewhat broad view of which litigation costs entities regulated under rate-of-return ratemaking should be permitted to recover. In
Iroquois Gas ,
the court vacated the Commission’s presumptive disallowance of a gas pipeline’s litigation costs defending alleged environmental violations during construction, reasoning that the Commission must analyze whether the purported environmental violations were for ratepayers’ benefit rather than simply presuming the imprudence of supposedly illegal activity. 145 F.3d at 399-403 . Similarly, in
Mountain States I,
939 F.2d at 1029-35 , the court vacated an FCC order denying a carrier’s recovery of antitrust litigation expenses, and, the same term, in
Mountain States Telephone and Telegraph Co. v. FCC,
939 F.2d 1035 (D.C.Cir.1991)
(“Mountain States II”),
remanded a rule presumptively denying recovery of litigation and judgment costs resulting from findings of illegal activity, expressing concern that such a rule might discourage utilities from taking appropriate legal risks that would ultimately benefit their ratepayers.
Id.
at 1042-47 .
The Commission stated that it did not consider
Iroquois Gas
apposite because in that case, the underlying activity — construction of the pipeline pursuant to the Commission’s certificate authority — was something over which the Commission had jurisdiction and whose prudence the Commission could evaluate. Opinion No. 435-B, 96 FERC at 62,070-71. By contrast, the Commission viewed SFPP’s underlying business decision to reverse flow on the six-inch line as “beyond the Commission’s remedial authority.” Proceeding on the premise that it lacks jurisdiction over market entry and exit, the Commission apparently takes the position that it is incapable of evaluating the prudence of legal expenses incurred in the course of either, and therefore cannot include them in common carrier rates.
The salient criterion under
Iroquois Gas
and
Mountain Stales II
for the recovery of legal expenditures by regulated entities is whether the underlying activity being
*1297
defended in the litigation serves the interests of ratepayers.
See Iroquois Gas,
145 F.3d at 401-02 ;
Mountain States II,
939 F.2d at 1043-47 . The court need not address whether the Commission can reasonably deny the recovery of all nonjurisdic-tional litigation expenses associated with “both [market] entry and exit by the pipeline,” Opinion No. 435-B, 96 FERC at 62,070, because the issue in this proceeding is more narrow, and arises only with regard to the inclusion of market exit costs in the East Line rates, not market entry costs in the West Line rates. Whatever might be a common carrier’s entitlement to recover any nonjurisdictional litigation costs associated with the initiation of common carrier service, it is not unreasonable for the Commission to refuse to allow a common carrier to charge ratepayers for the cost of taking capacity away from them. The Commission’s initial determination that the flow-reversal litigation at issue was unrelated to the provision of East Line service was reasonable, and we affirm on that basis. The Commission recognized that, unlike in
Iroquois Gas ,
SFPP’s litigation did not “arise[] under regulatory obligations that apply to the system as a whole,” and noted the “common sense observation by the East Line shippers that the costs and awards relating to their litigation will be borne primarily by themselves if the litigation and settlement costs are included in the East Line rates.”
Id.
at 62,071. As only the East Line rates were at issue, the court understands the Commission’s statement, that SFPP’s civil legal expenses arising from the reversal dispute are not those “that SFPP would normally incur in the conduct of its common carrier operations,” to refer narrowly to SFPP’s “common carrier operations” on the East Line, and not more broadly to SFPP’s “common carrier operations” generally. This approach is reasonable, because the cost of cancelling service is not a cost of providing it.
c.
Allocation of litigation costs
More problematic is the Commission’s decision that the East Line rates should bear half of SFPP’s recoverable litigation costs. Opinion No. 435-A, 91 FERC at 61,513. The rate proceeding included both East Line rates and the dispute about whether West Line rates were grandfathered. Some litigation costs may have been exclusive to each line, whereas others were common, but the record does not contain precise information regarding how much of SFPP’s legal expenses can be attributed to each portion of the rate litigation. The West Line accounts for roughly twice the throughput of the East Line, and the Commission had initially reasoned that due to the more complex nature of the West Line issues litigated in the regulatory proceeding, costs should be apportioned volumetrically between the lines. Opinion No. 435, 86 FERC at 61,106. On rehearing, the Commission reversed itself and split the costs evenly. Opinion No. 435-A, 91 FERC at 61,512. The Commission stated that the ALJ, who initially presided over the case, was “in a position to observe complexity and flow” of the litigation, and could have reasonably concluded that it was the East Line issues, not the West Line issues, that accounted for the “greater portion” of costs generated in the proceeding.
Id.
The ELS contend that the Commission departed from its well-established volumetric allocation policy for general costs without a rational basis, and thus was arbitrary and capricious in basing its allocation on which shippers created higher litigation costs. We see nothing problematic in an approach that attributes litigation costs to those for whose benefit the litigation is incurred, and prior Commission cases deal
*1298
ing with legal expenses have allocated them similarly.
See, e.g., Southern California Edison Co.,
56 FERC ¶ 61,003 , 61,-021, 1991 WL 519606 (1991). A volumetric approach might be appropriate for the recovery of commonly-incurred costs benefit-ting the entire system, but the Commission’s focus here on who “generate[d] the greater portion of a given litigation,” Opinion No. 435-A, 91 FERC at 61,513, is reasonable when litigation costs are specific to separately priced services.
The problem with the Commission’s litigation-cost allocation is more basic: it lacks substantive analysis. The court is unable to discern why the Commission decided that 50%, as opposed to 40%, 30%, or any other number, fairly reflects the portion of SFPP’s litigation expenses attributable to the East Line. It simply claimed to rely on the ALJ Decision for the 50% figure.
See
80 FERC at 65,167. The ALJ Decision, at best, implicitly adopts the allocation suggested by a Staff witness. Other than describing the Staffs proposal as being developed as a representative amount of litigation expenses for inclusion in the test year cost of service, the ALJ Decision provides no analysis of why such a distribution is warranted. Hence, the Commission’s reliance on the ALJ as being in the best position to observe the “complexity and flow” of the litigation leaves unexplained the basis for the allocation. While most of SFPP’s litigation cost recovery has been offset by unpaid reparations, and the difference in rates resulting from the allocation may ultimately not be significant, the Commission must still explain its decision. The 50% allocation may or may not be a fair reflection of SFPP’s rate litigation costs that were in fact attributable to the East Line. Accordingly, we remand for the Commission to explain its rationale for its allocation, either based on a 50-50 sharing between the East and West Lines or any other allocation it determines would be appropriate.
3.
Reconditioning Costs
SFPP sought to have included in its East Line rates a projected annual cost of $3 million for a 15-year pipeline reconditioning program replacing the protective coating on parts of the East Line. Before the Commission, SFPP claimed to have spent upwards of $5.9 million of these reconditioning costs between 1995 and 1998. While acknowledging SFPP’s expenditures on the project, the Commission refused to incorporate those costs, most of which were not incurred until after 1995, into SFPP’s cost of service because they were too uncertain at the end of the test period in 1994. Opinion No. 435, 86 FERC at 61,106-08. On rehearing, the Commission permitted SFPP to recover its actual expenses from shippers as part of the temporary surcharge it created for SFPP’s rate litigation and environmental expenses. Opinion No. 435-A, 91 FERC at 61,518-19. On further rehearing, however, the Commission reversed itself again and denied SFPP all recovery of its refurbishing costs. Opinion No. 435-B, 96 FERC at 62,078-79.
Under its cost of service regulations, the Commission uses a “test year” methodology to determine a pipeline’s annual cost of service. This approach looks to the actual costs the carrier incurs in the “test year” and then adjusts for any “known and measurable with reasonably accuracy” costs that “will become effective within nine months after the last month of the available actual experience utilized in the filing.” 18 C.F.R. § 346.2 (a)(1)(ii) (2004). The test year methodology accounts for the somewhat counterintuitive quality of these proceedings. The Commission, in issuing decisions after 1999 setting SFPP’s cost of service for years after 1994, looked
*1299
not to SFPP’s actual costs in those years but rather to what one could have predicted those costs to be, based on what was known in 1994. The Commission noted in Opinion No. 435 that it considers the test year a “relatively rigid concept simply because there must be some point at which the record closes and there is a known, factual basis for the conclusions.” 86 FERC at 61,108. Although this statement appears to mark a change from Commission policy in cases preceding the implementation of its cost of service regulations, where it indicated that it would approach, test years more flexibly,
see, e.g., Lake-head,
71 FERC at 62,313;
Williams Pipe Line Co.,
21 FERC at 61,658, the Commission’s current cost of service regulations provide that it “may allow reasonable deviation from the test period” for “good cause shown.” 18 C.F.R. § 346.2 (a)(1)(ii).
The ALJ, using 1993 as the base year, decided that the refurbishing costs could not be recovered as part of SFPP’s cost of service because the costs had not yet been incurred at that time, and SFPP’s predictions of future costs were too uncertain. Finding that SFPP’s board had not committed to the refurbishing program as late as 1995 and was simply funding the program year-by-year rather than committing itself to the entire proposed 15-year program, the ALJ reached a series of conclusions: that SFPP might decide to abandon the project or scale it back in the future, that the overall plan was subject to change, that there was little documentation to support estimates of the costs, and that it was uncertain whether significant amounts of the pipeline scheduled for refurbishing might be so corroded as to require outright replacement, which would be treated as a capital investment and factored into the rate base, not as an expense added to cost of service. In Opinion No. 435, the Commission essentially affirmed the ALJ’s decision. 86 FERC at 61,106-08.
SFPP contends that the Commission, which used a 1994 base period and the nine-month test period in 1995, could not reasonably affirm the ALJ’s decision, which was based on data from an earlier period. There is some record evidence supporting SFPP’s claim that it had more firmly committed to the reconditioning project, including beginning refurbishment of several miles of pipeline in 1995, within “nine months after the last month” of 1994.
Cf.
18 C.F.R. § 346.2 (a)(1)(ii). There was testimony that SFPP’s board had approved the project by 1994, that SFPP had recoated 13 miles of the pipeline in 1995, and that its prospective cost estimates were based upon its actual costs thus far.
Nonetheless, it was not unreasonable of the Commission to continue to have doubts about locking so large an expense into SFPP’s cost of service (or, to put it more aptly given the test year methodology used here, it was not unreasonable for the Commission to have thought that doubts about the scope of the reconditioning project would still have been proper in 1995). At most the evidence before the Commission showed that, by 1995, SFPP had begun refurbishing certain portions of its pipeline; there was no guarantee from SFPP that the refurbishing would be as ambitious and expensive as claimed. Embedding SFPP’s projections into its cost of service would have required its customers to pay for the refurbishing even if the project ultimately resulted in far smaller expenditures than those SFPP had projected. Indeed, given that SFPP now claims to have spent roughly $6 million on the project over four years, when it had predicted costs of at least $3 million a year over fifteen years, the Commission’s judgment has been validated by hindsight.
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This does not end our inquiry, however, for SFPP also contends that having denied inclusion of reconditioning costs in SFPP’s cost of service, it was arbitrary for the Commission not to permit recovery in a surcharge of SFPP’s actual costs in 1995-98, which were not found to be imprudently incurred. The Commission’s legitimate doubts over the ultimate scope and cost of the reconditioning do not explain the basis for the Commission’s decision to deny recovery once actual costs of the project were known. Its decision, rather, stems from a combination of the Commission’s test year approach and its interpretation of the filed rate doctrine. In Opinion No. 435-A, the Commission permitted SFPP to recover its actual reconditioning costs as part of the same surcharge whereby it permitted recovery of SFPP’s regulatory litigation costs, similarly offset by any unpaid reparations; any cost not so offset could be included in a surcharge amortized over five years. Yet in Opinion No. 435-B, presented with SFPP’s claim that it had expended $5.9 million in actual East Line refurbishing costs between 1995 and 1998, the Commission denied recovery altogether because the expenditures “were not incurred in the 1994 cost of service test period.” 96 FERC at 62,078. In responding to protests that its Opinion No. 435-A ruling violated the filed rate doctrine, the Commission concluded “[u]pon further review” that allowing a surcharge for costs not incurred in the test period or with any regularity thereafter “would permit SFPP to recover costs after the fact which were not even present in the test year itself and which thereafter could not be recovered in a cost of service rate filing,” and that “[t]o do so after the fact raises serious questions under the filed rate doctrine.” Opinion No. 435-B, 96 FERC at 62,078.
The difficulty for the court stems from three sources: the Commission’s apparent failure in its test year approach to articulate a clear and consistent approach for dealing with the prudently incurred costs of providing pipeline service that do not regularly recur, the Commission’s failure to explain adequately why SFPP’s reconditioning costs would not be recoverable in a cost of service rate filing, and its failure to articulate why such a surcharge would violate the filed rate doctrine. Some prudent expenditures involved in the operation of a pipeline that are not capitalized, such as, for instance, rate litigation or refurbishing, are bound to be one-time or infrequent expenditures. A “test year” snapshot of a pipeline’s operating costs, therefore, if applied too simplistically, risks over or under-stating the “real” costs of providing pipeline service, depending on whether such costs happen, by chance, to fall in a test year or not. We do not understand the Commission to apply the test year concept so simplistically; its regulations deal with the possible overstating problem by disallowing nonrecurring costs as part of the cost of service,
see
18 C.F.R. § 346.2 (a)(l)(I), and both under and overstating problems by permitting deviation from the test year “for good cause shown,”
id.
§ 346.2(a)(l)(ii). Yet the Commission’s approach in the instant case does not appear to deal consistently with costs incurred outside the test year, as evidenced by its different treatment of SFPP’s rate litigation and reconditioning costs between 1995 and 1998. Both appear to be prudent, otherwise recoverable costs; both are nonrecurring (in the sense that they will not be permanent expenditures SFPP can be expected to incur each year); both were incurred chiefly outside the 1994 test year; and the Commission initially held that both past expenses could be recovered in prospective rates through a temporary surcharge because of “benefits that flowed to the system when the costs were in
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curred.” Opinion No. 435-A, 91 FERC at 61,518.
The Commission then reversed course in Opinion No. 435-B and disallowed recovery of the reconditioning costs only. Its reasoning for disallowing one surcharge but permitting the other was that “unlike the [Commission] regulatory costs, none of [SFPP’s reconditioning costs] were incurred in the test period.” 96 FERC at 62,078. The rate litigation surcharge included SFPP’s actual costs after 1994. So the Commission’s ruling suggests that it matters, to recovery of costs incurred outside of the test year, whether a carrier also incurred costs of the same general nature in the test year itself. The logic behind this distinction, as applied to costs that benefit the carrier’s system but are not expected to regularly recur, is neither explained in Opinion No. 435-B itself, nor is it obvious. Should the Commission wish to rely on this reasoning on remand, it must articulate and justify more carefully what its policy on the recoverability of nontest-year expenses is.
The Commission did explain that SFPP’s rates were indexed to account for cost increases after the test year, and that SFPP could not meet the “substantial divergence” standard for showing that indexing failed to account for increases in its cost of service due to reconditioning expenses after 1994.
Cf.
18 C.F.R. § 342.4 (a) (2004). Assuming that the Commission can explain its different treatment of rate litigation and reconditioning costs incurred in years after the 1994 test year, this may be a reasonable basis for denying recovery, but the Commission’s opinion provides no analysis for why it is true. Where the Commission had found SFPP’s cost of service to be roughly $14 million a year, SFPP was claiming reconditioning costs of roughly $1 million a year, a not insubstantial amount. The Commission provided no estimate or analysis of how any supplemental revenues to SFPP resulting from rate indexing, or from increased throughput in years after 1994, compare to those expenses.
The Commission also stated that permitting recovery of the refurbishing costs “after the fact” would “raise serious questions under the filed rate doctrine.” Opinion No. 435-B, 96 FERC at 62,078. The filed rate doctrine “forbids a regulated entity to charge rates for its services other than those properly filed with the appropriate federal regulatory authority.”
Arkansas Louisiana Gas Co. v. Hall,
453 U.S. 571, 577 , 101 S.Ct. 2925, 2930 , 69 L.Ed.2d 856 (1981). The Commission did not articulate what type of “serious questions” it thought such recovery would raise. Because a prospective surcharge would presumably be on file with the Commission, the court presumes that the Commission meant that an amortized surcharge, by prospectively recovering SFPP’s expenses from past years, would violate the related rule against retroactive ratemaking, which requires that “a utility may not set rates to recoup past losses, nor may the Commission prescribe rates on that principle.”
Southern California Edison Co. v. FERC,
805 F.2d 1068 , 1070 n. 2 (D.C.Cir.1986) (quoting
Nader v. FCC,
520 F.2d 182 , 202 (D.C.Cir.1975)).
This logic, again, raises the question of why such recovery is any more permissible for rate litigation expenses than it is for reconditioning costs. The Commission seems to place SFPP in a Catch-22: it cannot recover its reconditioning costs prospectively or contemporaneously because the cost of the project is too uncertain until the costs are incurred, but then once the costs are certain it is too late because recovery would involve retroactive charges. Absent a better explanation for the Commission’s conclusion that SFPP
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has recovered its reconditioning costs through the indexed rates, it is unclear how the costs of any multi-year project whose cost is not “known and measurable with reasonable certainty” in advance, 18 C.F.R. § 346.2 (a)(1)(ii), could ever be recovered, were this reasoning to be consistently adopted. The Commission ruled in Opinion No. 435-A that prospective recovery of SFPP’s reconditioning costs would be appropriate because of “benefits that flowed to the system when the costs were incurred,” 91 FERC at 61,518, implying that it initially did not view the rule against retroactive rulemaking as an obstacle because the expenses provided an ongoing benefit that would continue to accrue in future years. In light of the Commission’s failure to explain why it now considers the rule against retroactive rule-making (or the filed rate doctrine) to bar recovery, and because no party has briefed this question in any detail, the court remands so that the Commission, if it wishes to continue relying on this reasoning, may better explain it.
The Commission may have answers to these concerns, but they are not provided in the Opinions on review. SFPP’s shippers are presently enjoying the benefits of what appears to be an expensive pipeline reconditioning program without sharing in any of its costs. If, in the Commission’s opinion, they should not have to, the Commission needs to provide a more thorough explanation of why not. Accordingly, we remand SFPP’s request to recover its reconditioning costs for the East Line between 1995 and 1998 to the Commission for further consideration.
III. Reparations
A.
Background and Proceedings Below
After determining that SFPP’s East Line rates were not just and reasonable, the ALJ ordered SFPP to pay reparations to the ELS which had filed complaints against the rates. ALJ Decision, 80 FERC at 61,308. In Opinion No. 435, the Commission considered various objections to the reparations on the part of both SFPP and the shippers but reaffirmed that SFPP was to pay reparations as determined by the Commission.
See id.
at 61,111-14. Specifically, the Commission ruled that the period for the calculation of reparations would run from the date of each complaint until March 31, 1999, the effective date of revised East Line rates required by Opinion No. 435.
In calculating the potential reparations, the Commission retroactively applied the test year approach it had used to set SFPP’s prospective rates: SFPP was to develop an East Line cost of service for a test year, 1994; design a rate that reflected that cost of service; index that rate to December 31, 1998; and apply that indexed rate to designated volumes adopted by Opinion No. 435 for each calendar year for which an indexed rate had been developed. Using the new cost of service thus established for years 1994-1998 and partial year 1999, SFPP was to determine whether the revenues for each period resulted in an over or under-recovery of its cost of service. FERC’s order permitted SFPP to “net out its over and under recoveries for each year and determine that net amount, if any, that is due its East Line Shippers.”
Id.
at 61,114. FERC ordered a similar calculation of reparations for years prior to 1994 based on the calculation of under or over-recovery of cost of service in those years. As to reparations in general, FERC held that no shipper was entitled to reparations for periods prior to the filing date of a complaint.
Id.
at 61,112-13.
On rehearing, FERC held that Navajo was the only complainant that had filed a challenge to East Line rates. Thus, only
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Navajo could recover reparations. Opinion No. 435-A, 91 FERC at 61,514. FERC granted Navajo reparations beginning one month prior to the filing of its December 23, 1993, complaint to SFPP’s rates. FERC also noted that Navajo had entered a settlement with SFPP in 1989. That settlement barred Navajo from bringing action against SFPP until November 23, 1993. With those provisos, FERC ordered SFPP to calculate the limited reparations still in order on the East Line based on the difference between per-barrel rates charged and per-barrel rates that would have been charged had SFPP charged cost-based rates using a 1994 test year, and to index such rates annually going forward — in other words, the difference between the charged rates and the rates that SFPP should have charged. In sum, the Commission modified its prior order and decreed that:
SFPP will calculate the gross reparations that would be due if all shippers that had used the East Line had filed complaints for the applicable reparations period ... establishing] the total revenue that was received in excess of the new East Line rates established by the prior order. Navajo will be paid its
pro rata
share of the reparations for the relevant time frame.
Id.
at 61,518. The Commission noted that because Navajo was the only shipper entitled to reparations, the calculations “should leave a surplus of revenues in excess of the East Line restated cost of service between the beginning of the reparations period and the actual date on which the restated rates began to be collected by SFPP.”
Id.
The shippers petitioned for rehearing of FERC’s reconsideration order, which FERC granted in part. This time, FERC held that Chevron, Western, ConoeoPhil-lips, and ExxonMobil were, like Navajo, entitled to reparations for overcharges that occurred two years prior to the filing of their complaints. Opinion No. 435-B, 96 FERC at 62,071-74. FERC held that Valero was not entitled to reparations, because its complaint was filed after August 7, 1995, the last date complaints were consolidated in the proceedings.
Id.
at 62,072. The Commission subsequently clarified Opinion No. 435-B by stating that Chevron’s eligibility for reparations was determined as of its August 3, 1993 complaint, not a protest it filed September 23, 1992. Clarification and Rehearing Order, 97 FERC ¶ 61,138 .
SFPP now argues that the Commission ought not have awarded any reparations whatsoever. Navajo contends that it was improperly denied reparations prior to November 23, 1993. Chevron alleges that FERC improperly set the commencement date for calculating its reparations. And Valero, BP WCP, and Chevron all claim that they were improperly denied reparations.
B.
Analysis
1.
SFPP
SFPP argues that the underlying orders were arbitrary and capricious for four related reasons. First, SFPP contends that awarding ELS reparations is impermissible retroactive ratemaking, in violation of the Supreme Court’s decision in
Arizona Grocery Co. v. Atchison, Topeka & Santa Fe Railway Co.,
284 U.S. 370 , 52 S.Ct. 183 , 76 L.Ed. 348 (1932). Second, it asserts that FERC’s award of pre-complaint reparations violates the EPAct. Third, SFPP advances that FERC improperly awarded reparations based on a “test period,” disregarding damages actually suffered and proved by complainants. Finally, SFPP argues that FERC failed to consider substantial arguments — such as the novelty and complexity of SFPP’s rate case — that
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militated against awarding reparations. For the reasons stated below, we reject all four claims.
a.
The
Arizona Grocery
Rule
Arizona Grocery
proscribes “the retroactive revision of established rates through ex post reparations.”
Verizon Tel Cos. v. FCC,
269 F.3d 1098, 1107 (D.C.Cir.2001);
see also Ala. Power Co. v. ICC,
852 F.2d 1361 , 1373 (D.C.Cir.1988). Otherwise put,
Arizona Grocery
bars reparations that retroactively change a final Commission-approved rate. SFPP relies on
Arizona Grocery
to argue that Opinion No. 436 was a final order prescribing just and reasonable rates, and thus FERC was barred from awarding reparations when SFPP’s rate was effectively further lowered as a result of FERC’s subsequent orders. SFPP argues that Opinion No. 435 was a final order setting rates “to be thereafter observed” under ICA Section 15(1), and therefore that the subsequent orders were retroactive changes of Opinion No. 435. We disagree.
Arizona Grocery
is of no help to SFPP in this case.
Arizona Grocery
applies only where the Commission has “declared what is the maximum reasonable rate to be charged by a carrier.” 284 U.S. at 390 , 52 S.Ct. at 186 . Yet FERC did not finalize a maximum reasonable rate in Opinion No. 435 and in fact repeatedly stated it was not doing so. Thus Opinion No. 435 set no final rate; rather, FERC only established a final rate at the completion of the OR92-8 proceedings.
SFPP, L.P.,
100 FERC ¶ 61,353 , 62,625, 2002 WL 31986493 (2002) (“September 26 Order”). The OR92-8 proceedings were compliance filings. SFPP’s filing in Docket No. OR92-8-013 showed SFPP’s calculations for determining how its East Line rates should be structured to reflect the requirements

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Source: Frix Law Library, https://www.frixlaw.com/law-library/cases/786887. Public record. Not legal advice.