Morgan Stanley Capital Group Inc. v. Public Util. Dist. No. 1 of Snohomish Cty.

delivered the opinion of the Court.

Under the Mobile-Sierra doctrine, the Federal Energy Regulatory Commission (FERC or Commission) must presume that the rate set out in a freely negotiated wholesale-energy contract meets the “just and reasonable” requirement imposed by law. The presumption may be overcome only if FERC concludes that the contract seriously harms the public interest. These cases present two questions *531about the scope of the Mobile-Sierra doctrine: First, does the presumption apply only when FERC has had an initial opportunity to review a contract rate without the presumption? Second, does the presumption impose as high a bar to challenges by purchasers of wholesale electricity as it does to challenges by sellers?

I

A

Statutory Background

The Federal Power Act (FPA), 41 Stat. 1063, as amended, gives the Commission1 the authority to regulate the sale of electricity in interstate commerce—a market historically characterized by natural monopoly and therefore subject to abuses of market power. See 16 U. S. C. § 824 et seq. (2000 ed. and Supp. V). Modeled on the Interstate Commerce Act, the FPA requires regulated utilities to file compilations of their rate schedules, or “tariffs,” with the Commission, and to provide service to electricity purchasers on the terms and prices there set forth. §824d(e). Utilities wishing to change their tariffs must notify the Commission 60 days before the change is to go into effect. §824d(d). Unlike the Interstate Commerce Act, however, the FPA also permits utilities to set rates with individual electricity purchasers through bilateral contracts. § 824d(e), (d). As we have explained elsewhere, the FPA “departed from the scheme of purely tariff-based regulation and acknowledged that contracts between commercial buyers and sellers could be used in ratesetting.” Verizon Communications Inc. v. FCC, 535 U. S. 467, 479 (2002). Like tariffs, contracts must be filed with the Commission before they go into effect. 16 U. S. C. § 824d(c), (d).

The FPA requires all wholesale-electricity rates to be “just and reasonable.” § 824d(a). When a utility files a new *532rate with the Commission, through a change to its tariff or a new contract, the Commission may suspend the rate for up to five months while it investigates whether the rate is just and reasonable. § 824d(e). The Commission may, however, decline to investigate and permit the rate to go into effect— which does not amount to a determination that the rate is “just and reasonable.” See 18 CFR §35.4 (2007). After a rate goes into effect, whether or not the Commission deemed it just and reasonable when filed, the Commission may conclude, in response to a complaint or on its own motion, that the rate is not just and reasonable and replace it with a lawful rate. 16 U. S. C. § 824e(a) (2000 ed., Supp. V).

The statutory requirement that rates be “just and reasonable” is obviously incapable of precise judicial definition, and we afford great deference to the Commission in its rate decisions. See FPC v. Texaco Inc., 417 U. S. 380, 389 (1974); Permian Basin Area Rate Cases, 390 U. S. 747, 767 (1968). We have repeatedly emphasized that the Commission is not bound to any one ratemaking formula. See Mobil Oil Exploration & Producing Southeast, Inc. v. United Distribution Cos., 498 U. S. 211, 224 (1991); Permian Basin, supra, at 776-777. But FERC must choose a method that entails an appropriate “balancing of the investor and the consumer interests.” FPC v. Hope Natural Gas Co., 320 U. S. 591, 603 (1944). In exercising its broad discretion, the Commission traditionally reviewed and set tariff rates under the “cost-of-service” method, which ensures that a seller of electricity recovers its' costs plus a rate of return sufficient to attract necessary capital. See J. McGrew, Federal Energy Regulatory Commission 152, 160-161 (2003) (hereinafter McGrew).

In two cases decided on the same day in 1956, we addressed the authority of the Commission to modify rates set bilaterally by contract rather than unilaterally by tariff. In United Gas Pipe Line Co. v. Mobile Gas Service Corp., 350 U. S. 332, we rejected a natural-gas utility’s argument that *533the Natural Gas Act’s requirement that it file all new rates with the Commission authorized it to abrogate a lawful contract with a purchaser simply by filing a new tariff, see id., at 336-337. The filing requirement, we explained, is merely a precondition to changing a rate, not an authorization to change rates in violation of a lawful contract (i. e., a contract that sets a just and reasonable rate). See id., at 339-344.

In FPC v. Sierra Pacific Power Co., 350 U. S. 348, 352-353 (1956), we applied the holding of Mobile to the analogous provisions of the FPA, concluding that the complaining utility could not supersede a contract rate simply by filing a new tariff. In Sierra, however, the Commission had concluded not only (contrary to our holding) that the newly filed tariff superseded the contract, but also that the contract rate itself was not just and reasonable, “solely because it yield[ed] less than a fair return on the net invested capital” of the utility. 350 U. S., at 355. Thus, we were confronted with the question of how the Commission may evaluate whether a contract rate is just and reasonable.

We answered that question in the following way:

“[T]he Commission’s conclusion appears on its face to be based on an erroneous standard. . . . [W]hile it may be that the Commission may not normally impose upon a public utility a rate which would produce less than a fair return, it does not follow that the public utility may not itself agree by contract to a rate affording less than a fair return or that, if it does so, it is entitled to be relieved of its improvident bargain. ... In such circumstances the sole concern of the Commission would seem to be whether the rate is so low as to adversely affect the public interest — as where it might impair the financial ability of the public utility to continue its service, cast upon other consumers an excessive burden, or be unduly discriminatory.” Id., at 354-355 (emphasis deleted).

*534As we said in a later case, “[t]he regulatory system created by the [FPA] is premised on contractual agreements voluntarily devised by the regulated companies; it contemplates abrogation of these agreements only in circumstances of unequivocal public necessity.” Permian Basin, supra, at 822.

Over the past 50 years, decisions of this Court and the Courts of Appeals have refined the Mobile-Sierra presumption to allow greater freedom of contract. In United Gas Pipe Line Co. v. Memphis Light, Gas and Water Div., 358 U. S. 103, 110-113 (1958), we held that parties could contract out of the Mobile-Sierra presumption by specifying in their contracts that a new rate filed with the Commission would supersede the contract rate. Courts of Appeals have held that contracting parties may also agree to a middle option between Mobile-Sierra and Memphis Light: A contract that does not allow the seller to supersede the contract rate by filing a new rate may nonetheless permit the Commission to set aside the contract rate if it results in an unfair rate of return, not just if it violates the public interest. See, e. g., Papago Tribal Util. Auth. v. FERC, 723 F. 2d 950, 953 (CADC 1983); Louisiana Power & Light Co. v. FERC, 587 F. 2d 671, 675-676 (CA5 1979). Thus, as the Mobile-Sierra doctrine has developed, regulated parties have retained broad authority to specify whether FERC can review a contract rate solely for whether it violates the public interest or also for whether it results in an unfair rate of return. But the Mobile-Sierra presumption remains the default rule.

Moreover, even though the challenges in Mobile and Sierra were brought by sellers, lower courts have concluded that the Mobile-Sierra presumption also applies where a purchaser, rather than a seller, asks FERC to modify a contract. See Potomac Elec. Power Co. v. FERC, 210 F. 3d 403, 404-405, 409-410 (CADC 2000); Boston Edison Co. v. FERC, 856 F. 2d 361, 372 (CA1 1988). This Court has seemingly blessed that conclusion, explaining that under the FPA, “[w]hen commercial parties . . . avail themselves of rate *535agreements, the principal regulatory responsibility [is] not to relieve a contracting party of an unreasonable rate.” Verizon, 535 U. S., at 479 (citing Sierra, supra, at 355).

Over the years, the Commission began to refer to the two modes of review—one with the Mobile-Sierra presumption and the other without—as the “public interest standard” and the “just and reasonable standard.” See, e. g., In re Southern Company Servs., Inc., 39 FERC ¶ 63,026, pp. 65,134, 65,141 (1987). Decisions from the Courts of Appeals did likewise. See, e. g., Kansas Cities v. FERC, 723 F. 2d 82, 87-88 (CADC 1983); Northeast Utils. Serv. Co. v. FERC, 993 F. 2d 937, 961 (CA1 1993). We do not take this nomenclature to stand for the obviously indefensible proposition that a standard different from the statutory just-and-reasonable standard applies to contract rates. Rather, the term “public interest standard” refers to the differing application of that just-and-reasonable standard to contract rates. See Philadelphia Elec. Co., 58 F. R C. 88, 90 (1977). (It would be less confusing to adopt the Solicitor General’s terminology, referring to the two differing applications of the just-and-reasonable standard as the “ordinary” “just and reasonable standard” and the “public interest standard.” See Reply Brief for Respondent FERC 6.)

B

Recent FERC Innovations; Market-Based Tariffs

In recent decades, the Commission has undertaken an ambitious program of market-based reforms. Part of the impetus for those changes was technological evolution. Historically, electric utilities had been vertically integrated monopolies. For a particular geographic area, a single utility would control the generation of electricity, its transmission, and its distribution to consumers. See Midwest ISO Transmission Owners v. FERC, 373 F. 3d 1361, 1363 (CADC 2004). Since the 1970’s, however, engineering innovations have lowered the cost of generating electricity and transmit*536ting it over long distances, enabling new entrants to challenge the regional generating monopolies of traditional utilities. See generally New York v. FERC, 535 U. S. 1, 7-8 (2002); Public Util. Disk No. 1 of Snohomish Cty. v. FERC, 272 F. 3d 607, 610 (CADC 2001) (per curiam).

To take advantage of these changes, the Commission has attempted to break down regulatory and economic barriers that hinder a free market in wholesale electricity. It has sought to promote competition in those areas of the industry amenable to competition, such as the segment that generates electric power, while ensuring that the segment of the industry characterized by natural monopoly — namely, the transmission grid that conveys the generated electricity — cannot exert monopolistic influence over other areas. See New York, supra, at 9-10; Snohomish, supra. To that end, FERC required in Order No. 888 that each transmission provider offer transmission service to all customers on an equal basis by filing an “open access transmission tariff.” Promoting Wholesale Competition Through Open Access NonDiscriminatory Transmission Services by Public Utilities, 61 Fed. Reg. 21540 (1996); see New York, supra, at 10-12. That requirement prevents the utilities that own the grid from offering more favorable transmission terms to their own affiliates and thereby extending their monopoly power to other areas of the industry.

To further pry open the wholesale-electricity market and to reduce technical inefficiencies caused when different utilities operate different portions of the grid independently, the Commission has encouraged transmission providers to establish “Regional Transmission Organizations” — entities to which transmission providers would transfer operational control of their facilities for the purpose of efficient coordination. Order No. 2000, 65 Fed. Reg. 810, 811-812 (2000); see Midwest ISO, supra, at 1364. It has encouraged the management of those entities by “Independent System Operators,” not-for-profit entities that operate transmission facili*537ties in a nondiseriminatory manner. See Midwest ISO, supra. In addition to coordinating transmission service, Regional Transmission Organizations perform other functions, such as running auction markets for electricity sales and offering contracts for hedging against potential grid congestion. See Blumsack, Measuring the Benefits and Costs of Regional Electric Grid Integration, 28 Energy L. J. 147 (2007).

Against this backdrop of technological change and market-based reforms, the Commission over the past two decades has begun to permit sellers of wholesale electricity to file “market-based” tariffs. These tariffs, instead of setting forth rate schedules or rate-fixing contracts, simply state that the seller will enter into freely negotiated contracts with purchasers. See generally Market-Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 697, 72 Fed. Reg. 39904 (2007) (hereinafter Market-Based Rates); McGrew 160-167. FERC does not subject the contracts entered into under these tariffs (as it subjected traditional wholesale-power contracts) to § 824d’s requirement of immediate filing, apparently on the theory that the requirement has been satisfied by the initial filing of the market-based tariffs themselves. See Brief for Respondent FERC 28-29 (hereinafter Brief for FERC).

FERC will grant approval of a market-based tariff only if a utility demonstrates that it lacks or has adequately mitigated market power, lacks the capacity to erect other barriers to entry, and has avoided giving preferences to its affiliates. See Market-Based Rates ¶ 7, 72 Fed. Reg. 39907. In addition to the initial authorization of a market-based tariff, FERC imposes ongoing reporting requirements. A seller must file quarterly reports summarizing the contracts that it has entered into, even extremely short-term contracts. See California ex rel. Lockyer v. FERC, 383 F. 3d 1006, 1013 (CA9 2004). It must also demonstrate every four months *538that it still lacks or has adequately mitigated market power. See ibid. If FERC determines from these filings that a seller has reattained market power, it may revoke the authority prospectively. See Market-Based Rates ¶ 5, 72 Fed. Reg. 39906. And if the Commission finds that a seller has violated its Regional Transmission Organization’s market rules, its tariff, or Commission orders, the Commission may take appropriate remedial action, such as ordering refunds, requiring disgorgement of profits, and imposing civil penalties. See ibid.

Both the Ninth Circuit and the D. C. Circuit have generally approved FERC’s scheme of market-based tariffs. See Lockyer, supra, at 1011-1013; Louisiana Energy & Power Auth. v. FERC, 141 F. 3d 364, 365 (CADC 1998). We have not hitherto approved, and express no opinion today, on the lawfulness of the market-based-tariff system, which is not one of the issues before us. It suffices for the present cases to recognize that when a seller files a market-based tariff, purchasers no longer have the option of buying electricity at a rate set by tariff and contracts no longer need to be filed with FERC (and subjected to its investigatory power) before going into effect.

C

California’s Electricity Regulation and Its Consequences

In 1996, California enacted Assembly Bill 1890 (AB 1890), which massively restructured the California electricity market. See 1996 Cal. Stat. ch. 854 (codified at Cal. Pub. Util. Code Ann. §§ 330-398.5 (West 2004 and Supp. 2008)); see generally Cudahy, Whither Deregulation: A Look at the Portents, 58 N. Y. U. Annual Survey of Am. Law 155, 172-185 (2001) (hereinafter Cudahy). The bill transferred operational control of the transmission facilities of California’s three largest investor-owned utilities to an Independent Service Operator (Cal-ISO). See Pacific Gas & Elec. Co. v. *539FERC, 464 F. 3d 861, 864 (CA9 2006). It also established the California Power Exchange (CalPX), a nonprofit entity that operated a short-term market — or “spot market” — for electricity. The bill required California’s three largest investor-owned utilities to divest most of their electricity-generation facilities. It then required those utilities to purchase and sell the bulk of their electricity from and to the CalPX’s spot market, permitting only limited leeway for them to enter into long-term contracts. See Public Util. Dist. No. 1 of Snohomish Cty. v. FERC, 471 F. 3d 1053, 1068 (CA9 2006) (case below).

In 1997, FERC approved the Cal-ISO as consistent with the requirements for an Independent Service Operator established in Order No. 888. FERC also approved the CalPX and the investor-owned utilities’ authority to make sales at market-based rates in the CalPX, finding that, in light of the divesture of their generation units and other conditions imposed under the restructuring plan, those utilities had adequately mitigated their market power. See Pacific Gas & Elec. Co., 81 FERC ¶ 61,122, pp. 61,435, 61,435-61,436, 61,537-61,548 (1997).

The CalPX opened for business in March 1998. In the summer of 1999, it expanded to include an auction for sales of electricity under “forward contracts”—contracts in which sellers promise to deliver electricity more than one day in the future (sometimes many years). But the participation of California’s large investor-owned utilities in that forward market was limited because, as we have said, AB 1890 strictly capped the amount of power that they could purchase outside of the spot market. See 471 F. 3d, at 1068.

That diminishment of the role of long-term contracts in the California electricity market turned out to be one of the seeds of an energy crisis. In the summer of 2000, the price of electricity in the CalPX’s spot market jumped dramatically — more than fifteenfold. See ibid. The increase was the result of a combination of natural, economic, and regula*540tory factors: “flawed market rules; inadequate addition of generating facilities in the preceding years; a drop in available hydropower due to drought conditions; a rupture of a major pipeline supplying natural gas into California; strong growth in the economy and in electricity demand; unusually high temperatures; an increase in unplanned outages of extremely old generating facilities; and market manipulation.” CAlifornians for Renewable Energy, Inc. v. Sellers of Energy and Ancillary Servs., 119 FERC ¶ 61,058, pp. 61,243, 61,247 (2007). Because California’s investor-owned utilities had for the most part been forbidden to obtain their power through long-term contracts, the turmoil in the spot market hit them hard. See Cudahy 174. The high prices led to rolling blackouts and saddled utilities with mounting debt.

In late 2000, the Commission took action. A central plank of its emergency effort was to eliminate the utilities’ reliance on the CalPX’s spot market and to shift their purchases to the forward market. To that end, FERC abolished the requirement that investor-owned utilities purchase and sell all power through the CalPX and encouraged them to enter into long-term contracts. See San Diego Gas & Electric Co. v. Sellers of Energy and Ancillary Servs., 93 FERC ¶ 61,294, pp. 61,980, 61,982 (2000); see also 471 F. 3d, at 1069. The Commission also put price caps on wholesale electricity. See San Diego Gas & Elec. Co. v. Sellers of Energy and Ancillary Servs., 95 FERC ¶ 61,418, p. 62,545 (2001). By June 2001, electricity prices began to decline to normal levels. Id., at 62,546.

D

Genesis of These Cases

The principal respondents in these cases are western utilities that purchased power under long-term contracts during that tumultuous period in 2000 and 2001. Although they are not located in California, the high prices in California spilled *541over into other Western States. See 471 F. 3d, at 1069. Petitioners are the sellers that entered into the contracts with respondents.

The contracts between the parties included rates that were very high by historical standards. For example, respondent Snohomish signed a 9-year contract to purchase electricity from petitioner Morgan Stanley at a rate of $105/ megawatt hour (MWh), whereas prices in the Pacific Northwest have historically averaged $24/MWh. The contract prices were substantially lower, however, than the prices that Snohomish would have paid in the spot market during the energy crisis, when prices peaked at $3,300/MWh. See id., at 1069-1070.

After the crisis had passed, buyer’s remorse set in and respondents asked FERC to modify the contracts. They contended that the rates in the contracts should not be presumed to be just and reasonable under Mobile-Sierra because, given the sellers’ market-based tariffs, the contracts had never been initially approved by the Commission without the presumption. See Nevada Power Co. v. Enron Power Marketing, Inc., 103 FERC ¶ 61,353, pp. 62,382, 62,387 (2003). Respondents also argued that contract modification was warranted even under the Mobile-Sierra presumption because the contract rates were so high that they violated the public interest. See 103 FERC, at 62,383, 62,387-62,395.

In a preliminary order, the Commission instructed the Administrative Law Judge (ALJ) to consider 12 different factors in deciding whether the presumption could be overcome for the contracts, such as the terms of the contracts, the available alternatives at the time of sale, the relationship of the rates to Commission benchmarks, the effect of the contracts on the financial health of the purchasers, and the impact of contract modification on national energy markets. After a hearing, the ALJ concluded that the Mobile-Sierra presumption should apply to the contracts and that the con*542tracts did not seriously harm the public interest. In fact, according to the ALJ, even if the Mobile-Sierra presumption did not apply, respondents would not be entitled to have the contracts modified. 103 FERC, at 62,390-62,394.

Between the ALJ’s decision and the Commission’s ruling, the Commission’s staff issued a report (Staff Report) concluding that unlawful activities of various sellers in the spot market had affected prices in the forward market. See id., at 62,396. Respondents raised the report at oral argument before the Commission, and some of them argued that petitioners “were unlawfully manipulating market prices, thereby engaging in fraud and deception in violation of their market-based rate tariffs.” Ibid. Petitioners contended, however, that the Staff Report demonstrated only a correlation between rates in the spot and forward markets, not a causal connection. See ibid.

FERC affirmed the ALJ. The Commission first held that the Mobile-Sierra presumption did apply to the contracts at issue. Although agreeing with respondents that the presumption applies only where FERC has had an initial opportunity to review a contract rate, the Commission relied on the somewhat metaphysical ground that the grant of market-based authority to petitioners qualified as that initial opportunity. See 103 FERC, at 62,388-62,389. The Commission then held that respondents could not overcome the Mobile-Sierra presumption. It recognized that the Staff Report had “found that spot market distortions flowed through to forward power prices,” 103 FERC, at 62,396-62,397, but concluded that this finding, even if true, was not “determinative” because:

“a finding that the unjust and unreasonable spot market caused forward bilateral prices to be unjust and unreasonable would be relevant to contract modification only where there is a ‘just and reasonable’ standard of review. . . . Under the ‘public interest’ standard, to jus*543tify contract modification it is not enough to show that forward prices became unjust and unreasonable due to the impact of spot market dysfunctions; it must be shown that the rates, terms and conditions are contrary to the public interest.” Id., at 62,397.

The Commission determined that under the factors identified in Sierra, as well as under a totality-of-the-circumstances test, respondents had not demonstrated that the contracts threatened the public interest. See 103 FERC, at 62,397-62,399. On rehearing, respondents reiterated their complaints, including their charge that “their contracts were the product of market manipulation by Enron, Morgan Stanley and other [sellers].” 105 FERC ¶ 61,185, pp. 61,979, 61,989 (2003). The Commission answered that there was “no evidence to support a finding of market manipulation that specifically affected the contracts at issue.” Id., at 61,989.

Respondents filed petitions for review in the Ninth Circuit, which granted the petitions and remanded to the Commission, finding two flaws in the Commission’s analysis.2 First, the court agreed with respondents that rates set by contract (whether pursuant to a market-based tariff or not) are presumptively reasonable only where FERC has had an initial opportunity to review the contracts without applying the Mobile-Sierra presumption. To satisfy that prerequisite under the market-based tariff regime, the court said, the Commission must promptly review the terms of contracts after their formation and must modify those that do not appear to be just and reasonable when evaluated without the Mobile-Sierra presumption (rather than merely revok*544ing market-based authority prospectively but leaving preexisting contracts intact). See 471 F. 3d, at 1075-1077, 1079-1085. This initial review must include an inquiry into “the market conditions in which the contracts at issue were formed,” and market “dysfunction” is a ground for finding a contract not to be just and reasonable. Id., at 1085-1087. Second, the Ninth Circuit held that even assuming that the Mobile-Sierra presumption applied, the standard for overcoming that presumption is different for a purchaser’s challenge to a contract, namely, whether the contract rate exceeds a “zone of reasonableness.” 471 F. 3d, at 1088-1090.

We granted certiorari. See 551 U. S. 1189 (2007).

II

A

Application of Mobile-Sierra Presumption to Contracts Concluded Under Market-Based Rate Authority

As noted earlier, the FERC order under review here agreed with the Ninth Circuit’s premise that the Commission must have an initial opportunity to review a contract without the Mobile-Sierra presumption, but maintained that the authorization for market-based rate authority qualified as that initial review. Before this Court, however, FERC changes its tune, arguing that there is no such prerequisite — or at least that FERC could reasonably conclude so and therefore that Chevron deference is in order. See Brief for FERC 20-21, 33-34; Chevron U. S. A. Inc. v. Natural Resources Defense Council, Inc., 467 U. S. 837 (1984). We will not uphold a discretionary agency decision where the agency has offered a justification in court different from what it provided in its opinion. See SEC v. Chenery Corp., 318 U. S. 80, 94-95 (1943). But FERC has lucked out: The Chenery doctrine has no application to these cases, because we conclude that the Commission was required, under our decision in Sierra, *545to apply the Mobile-Sierra presumption in its evaluation of the contracts here. That it provided a different rationale for the necessary result is no cause for upsetting its ruling. “To remand would be an idle and useless formality. Chenery does not require that we convert judicial review of agency action into a ping-pong game.” NLRB v. Wyman-Gordon Co., 394 U. S. 759, 766-767, n. 6 (1969) (plurality opinion).

We are in broad agreement with the Ninth Circuit on a central premise: There is only one statutory standard for assessing wholesale-electricity rates, whether set by contract or tariff — the just-and-reasonable standard. The plain text of the FPA states that “[a]ll rates . . . shall be just and reasonable.” 16 U. S. C. § 824d(a); see also § 824e(a) (2000 ed., Supp. V). But we disagree with the Ninth Circuit’s interpretation of Sierra as requiring (contrary to the statute) that the Commission apply the standard differently, depending on when a contract rate is challenged. In the Ninth Circuit’s view, Sierra was premised on the idea that “as long as the rate was just and reasonable when the contract was formed, there would be a presumption . . . that the reasonableness continued throughout the term of the contract.” 471 F. 3d, at 1077. In other words, so long as the Commission concludes (either after a hearing or by allowing a rate to go into effect) that a contract rate is just and reasonable when initially filed, the rate will be presumed just and reasonable in future proceedings.

That is a misreading of Sierra. Sierra was grounded in the commonsense notion that “[i]n wholesale markets, the party charging the rate and the party charged [are] often sophisticated businesses enjoying presumptively equal bargaining power, who could be expected to negotiate a ‘just and reasonable’ rate as between the two of them.” Verizon, 535 U. S., at 479. Therefore, only when the mutually agreed-upon contract rate seriously harms the consuming *546public may the Commission declare it not to be just and reasonable.3 Sierra thus provided a definition of what it means for a rate to satisfy the just-and-reasonable standard in the contract context — a definition that applies regardless of when the contract is reviewed. The Ninth Circuit, by contrast, essentially read Sierra “as the equivalent of an estoppel doctrine,” whereby an initial Commission opportunity for review prevents the Commission from modifying the rates absent serious future harm to the public interest. Tewksbury & Lim, Applying the Mobile-Sierra Doctrine to Market-Based Rate Contracts, 26 Energy L. J. 437, 457-458 (2005). But Sierra said nothing of the sort. And given that the Commission’s passive permission for a rate to go into effect does not constitute a finding that the rate is just and reasonable, it would be odd to treat that initial “opportunity for review” as curtailing later challenges.

The Ninth Circuit found support for its prerequisite in our decision in FPC v. Texaco Inc., 417 U. S. 380 (1974). In that case, we warned that the Commission’s attempt to rely solely on market forces to evaluate rates charged by small natural-gas producers was inconsistent with the Natural Gas Act’s insistence that rates be just and reasonable. See id., at 397. The Ninth Circuit apparently took this to mean that all initially filed contracts must be subject to review without the Mobile-Sierra presumption. But Texaco had nothing to do with that doctrine. It held that the Commission had improperly implemented a scheme of total deregulation by applying no standard of review at all to small-producer rates. See 417 U. S., at 395-397. It did not cast doubt on the proposition that in a proper regulatory scheme, the ordinary mode for evaluating contractually set rates is to look to *547whether the rates seriously harm the public interest, not to whether they are unfair to one of the parties that voluntarily assented to the contract. Cf. id., at 391, n. 4.

Nor do we agree with the Ninth Circuit that FERC must inquire into whether a contract was formed in an environment of market “dysfunction” before applying the Mobile-Sierra presumption. Markets are not perfect, and one of the reasons that parties enter into wholesale-power contracts is precisely to hedge against the volatility that market imperfections produce. That is why one of the Commission’s responses to the energy crisis was to remove regulatory barriers to long-term contracts. It would be a perverse rule that rendered contracts less likely to be enforced when there is volatility in the market. (Such a rule would come into play, after all, only when a contract formed in a period of “dysfunction” did not significantly harm the consuming public, since contracts that seriously harm the public should be set aside even under the Mobile-Sierra presumption.) By enabling sophisticated parties who weathered market turmoil by entering long-term contracts to renounce those contracts once the storm has passed, the Ninth Circuit’s holding would reduce the incentive to conclude such contracts in the future. Such a rule has no support in our case law and plainly undermines the role of contracts in the FPA’s statutory scheme.

To be sure, FERC has ample authority to set aside a contract where there is unfair dealing at the contract formation stage — for instance, if it finds traditional grounds for the abrogation of the contract such as fraud or duress. See 103 FERC, at 62,399-62,400 (“[T]here is no evidence of unfairness, bad faith, or duress in the original negotiations”). In addition, if the “dysfunctional” market conditions under which the contract was formed were caused by illegal action of one of the parties, FERC should not apply the Mobile-Sierra presumption. See Part III, infra. But the mere *548fact that the market is imperfect, or even chaotic, is no reason to undermine the stabilizing force of contracts that the FPA embraced as an alternative to “purely tariff-based regulation.” Verizon, 535 U. S., at 479. We may add that evaluating market “dysfunction” is a very difficult and highly speculative task — not one that the FPA would likely require the agency to engage in before holding sophisticated parties to their bargains.

We reiterate that we do not address the lawfulness of FERC’s market-based-rates scheme, which assuredly has its critics. But any needed revision in that scheme is properly addressed in a challenge to the scheme itself, not through a disfigurement of the venerable Mobile-Sierra doctrine. We hold only that FERC may abrogate a valid contract only if it harms the public interest.

B

Application of “Excessive Burden” Exception to High-Rate Challenges

We turn now to the Ninth Circuit’s second holding: that a “zone of reasonableness” test should be used to evaluate a buyer’s challenge that a rate is too high. In our view that fails to accord an adequate level of protection to contracts. The standard for a buyer’s challenge must be the same, generally speaking, as the standard for a seller’s challenge: The contract rate must seriously harm the public interest. That is the standard that the Commission applied in the proceedings below.