The Distance Between a Statutory Phrase and a Power Market
The most consequential energy policy of the last thirty years was not written by Congress. It was written by a five member commission exercising a ratemaking power granted in 1935, in language inherited from nineteenth century railroad regulation. The Federal Energy Regulatory Commission built the modern American electricity market, order by order, out of the requirement that rates be just and reasonable and not unduly discriminatory. No statute ever instructed FERC to create open transmission access, to form regional markets, to pay demand response at market prices, or to plan transmission across state lines. FERC did all of those things anyway, and the courts upheld them. This article is the practitioner guide to how that happened, to the jurisdictional line that limits FERC, and to the four other instruments, certificates, reliability standards, oil pipeline rates, and the preemption doctrine, that complete its authority.
That gap between the spare statutory text and the delivered policy is the widest point in this entire series. The Federal Power Act gives FERC jurisdiction over the transmission of electric energy in interstate commerce and the sale of electric energy at wholesale in interstate commerce, and it commands that rates and practices affecting those rates be just and reasonable. Out of that spare grant came the open access transmission tariff, the regional transmission organization, the organized wholesale auction, and the mandatory reliability standard. The Natural Gas Act gives FERC authority over interstate gas transportation and wholesale sales plus the certificate power over pipeline construction, and out of that grant came the modern interstate pipeline network, built on certificates that carry federal eminent domain authority. Understanding FERC means understanding instruments rather than statutes, because the instruments are where the law actually lives.
FERC is the least understood major regulator in the federal government for a structural reason. Most federal agencies implement statutes whose connection to daily life is visible: the tax code touches the paycheck, environmental rules touch the air, securities rules touch the retirement account. The commission’s work touches the light switch, and the light switch gives no hint of the market behind it. When a consumer pays an electric bill, the price reflects a state retail rate case built on top of wholesale auctions run by regional operators under tariffs FERC approved, which were themselves designed by commission orders issued under a 1935 statute. No part of that chain is visible at the meter. The result is that the most consequential energy policy of the last thirty years was made in a forum most citizens have never heard of, through instruments most lawyers outside the field have never read.
The One Test for this article is therefore practical rather than academic. A reader who finishes it should be able to state the jurisdictional line that governs American electricity and gas regulation, wholesale and interstate to the federal commission and retail to the states. The reader should understand why that line is genuinely hard to draw and how the Supreme Court has drawn it, through the directly affects test and the preemption cases. The reader should be able to name the orders that created open transmission access and regional markets. And the reader should grasp that a federal certificate for a gas pipeline confers the power of eminent domain, which makes the certificate docket the commission’s most politically contested forum. Those four competencies are the working knowledge of energy law practice, and this article builds each of them from the statute outward.
The article’s organization follows the five mechanisms of the brief. It begins with the agency Congress created and the commissioners who govern it, then draws the jurisdictional line and shows how the courts have policed it. It traces the just and reasonable standard from its railroad origins to its current role as the legal basis for market design. It walks through the market making orders in sequence, showing how each resolved the problem its predecessor left. It treats the pipeline certificate, the eminent domain power, and the environmental review as the commission’s siting function. It explains the frozen statute behind oil pipeline regulation and the reliability regime the 2005 act created. It corrects the misconception that FERC sets prices, describes the enforcement and compliance architecture, and notes the siting power Congress authorized that never matured. The jurisdiction and instrument table collects the whole system in one view.
The companion statute that created independent generation sits outside this article but completes the picture, and the statute that gave FERC its reliability authority is treated in its own article as well. The Public Utility Regulatory Policies Act of 1978 created the qualifying facility and with it the first class of independent generators FERC would later fold into competitive markets. The Energy Policy Act of 2005 added the reliability title that converted voluntary industry practice into enforceable federal law. Both statutes matter to this article only as anchors; the working law is in FERC orders.
The Agency Assigned: An Independent Commission Inside a Department
Congress created the Federal Energy Regulatory Commission in the Department of Energy Organization Act, Public Law 95-91, signed August 4, 1977. FERC began operating on October 1, 1977, absorbing the functions of the Federal Power Commission along with the Interstate Commerce Commission oil pipeline authority. Section 401(b) of the act, codified at 42 U.S.C. 7171, establishes FERC as an independent commission within the Department of Energy, and the legislative history shows Congress made a deliberate effort to preserve that independence. The House Government Operations Committee reported that a special effort was made to preserve the independence of action and decision of FERC and to insulate it from influences from other parts of the department.
FERC has five members. The President nominates them and the Senate confirms them. No more than three may belong to the same political party. They serve staggered five year terms, and the President designates one member as chairman, the executive and administrative head. A commissioner may be removed only for inefficiency, neglect of duty, or malfeasance in office. Those are the classic protections of an independent agency, and they explain why FERC can issue orders that reshape national markets without seeking the President’s approval. The party balance rule guarantees that a new President cannot instantly remake FERC, which in turn means that energy market policy moves more slowly than the electoral cycle and is negotiated through orders that outlast any single administration.
FERC does two kinds of legal work, and the distinction organizes everything it produces. In rulemaking it writes rules of general application, the market orders and the pro forma tariffs, through notice and comment procedures in which any interested party may file views. In adjudication it decides individual cases, the certificate applications, the tariff filings, the complaints, the enforcement matters, through trial type proceedings that build an evidentiary record. The rulemakings make the policy; the adjudications apply it. A practitioner reads the rulemaking orders to learn the market design and reads the adjudicated orders to learn how the design treats a particular set of facts. Both kinds of orders are reviewable in the courts of appeals after rehearing, and both accumulate into the body of commission precedent that functions, for the energy bar, the way case law functions for litigators.
The technical staff is the commission’s institutional memory. Because commissioners turn over with administrations while the staff endures, the deep knowledge of tariff mechanics, auction design, and pipeline engineering resides in career employees who draft the orders the commissioners vote on. That arrangement gives commission policymaking a continuity that the five member political leadership alone could not supply. A new chairman can redirect priorities, but the redirection moves through a staff that has administered the same tariffs for decades, which is one reason commission policy evolves by amendment to existing orders rather than by wholesale replacement. The order sequence from 888 to 1000 is the visible record of that evolutionary method.
Where does the commission get its statutory authority?
FERC exercises authority under the Federal Power Act for electricity, the Natural Gas Act for gas, the Interstate Commerce Act as frozen on October 1, 1977 for oil pipelines, and the reliability provisions added to the Federal Power Act in 2005. Congress assigned each subject through a statute, and FERC may not cross the boundaries those statutes set.
The five member structure matters for how FERC works in practice. Orders issue only with a quorum and a majority vote, so a single commissioner can block or force compromise on a major rulemaking. The staggered terms mean FERC is almost always a mix of appointees from different administrations, which shapes the character of its orders. Rulemaking at FERC is therefore a negotiation among five independent principals advised by a large technical staff, not the execution of a single executive will. The public record of that negotiation appears in concurrences and dissents attached to the orders, which the courts and the bar read as carefully as the orders themselves because they often predict the next round of policy.
The commission’s jurisdiction is defined by what it does not cover as much as by what it covers. The Federal Power Act applies to the transmission of electric energy in interstate commerce and the sale of electric energy at wholesale in interstate commerce, and it expressly excludes facilities used in local distribution and facilities used for the generation of electric energy. The Natural Gas Act applies to the transportation of natural gas in interstate commerce and the sale in interstate commerce of natural gas for resale for ultimate public consumption, and it expressly excludes local distribution, production, and gathering. Those exclusions are the states’ domain. Retail sales of electricity, the distribution wires that carry power to homes and businesses, the siting of power plants, local gas distribution, and gas production all belong primarily to state regulation. FERC sits on top of the interstate and wholesale layer, and the boundary between the layers is the central legal problem of the entire field.
The adjudicatory side of the commission’s work has its own procedural architecture. Contested rate cases and enforcement matters may be set for hearing before an administrative law judge, where the parties develop an evidentiary record through testimony and cross examination, and the judge issues an initial decision that the commission reviews. Trial staff, the commission’s own litigating arm in adjudicated cases, participates as a party representing the public interest, which means the commission effectively argues both sides of the case before it decides: the trial staff advocates a position and the commissioners judge it. Settlement judges help parties negotiate resolutions without a full hearing, and most adjudicated matters settle. The structure separates advocacy from decision within the agency, and the resulting record gives the courts of appeals the evidentiary basis for deferential review. A practitioner who understands that the commission is simultaneously a rulemaker, a prosecutor through its trial staff, and a judge learns to read each order for which role the commission was playing when it wrote it.
The Jurisdictional Line
American electricity regulation rests on one sentence of statutory geography. The commission regulates wholesale sales and transmission of electricity in interstate commerce and the transportation and wholesale sale of natural gas. The states regulate retail sales, distribution, and the siting of most generation. That sentence looks clean. It is not. A rule aimed at wholesale rates will inevitably change what happens at the retail meter, and a rule aimed at retail service will change the economics of the wholesale market. The physical system is a single machine; the legal system draws a line through it. Every major commission order of the last three decades has tested that line, and the Supreme Court has spent the last decade drawing it.
The difficulty is not an accident of drafting. It follows from the economics of electricity. Wholesale and retail are not separate markets but separate stages of the same transaction: the generator sells to the wholesaler, the wholesaler sells to the retailer, the retailer sells to the household, and the electrons are the same at every stage. Any rule that changes the wholesale price changes the retailer’s cost and therefore the retail price; any rule that changes retail consumption changes the load the wholesale market must serve and therefore the wholesale price. The statute’s division of the transaction into federal and state stages is thus a legal fiction imposed on an economic unity, and the fiction holds only because the courts have supplied tests for managing it. The directly affects test asks whether the federal rule operates on the wholesale stage directly enough to justify federal regulation; the preemption cases ask whether the state rule operates on the wholesale stage at all. Between those two inquiries the entire field is mapped.
The test the Court now applies came from FERC v. Electric Power Supply Association, decided January 25, 2016, by a six to two vote. The case concerned Order No. 745, the commission’s demand response rule, which requires organized wholesale markets to pay demand response resources the full locational marginal price when dispatching them is cost effective. Demand response is the commitment by electricity users to reduce consumption during high price periods. The challengers argued that regulating payments to retail consumers for not consuming electricity was regulation of retail sales, beyond the commission’s reach. Justice Kagan, writing for the majority, held that the Federal Power Act gives the commission authority over practices that directly affect wholesale rates, adopting the common sense construction of the act’s affecting language that the D.C. Circuit had developed. Demand response easily met that test because paying consumers to reduce demand displaces higher priced generation bids and necessarily lowers the wholesale price. The Court added two further points. First, the commission had not regulated retail sales because its rule permitted states to prohibit their retail consumers from participating in wholesale demand response programs, so no state was forced to accept federal terms at the retail meter. Second, the challengers’ narrow reading would conflict with the act’s core purposes, which include protecting consumers against excessive prices. The Court also upheld the commission’s compensation method, the full locational marginal price when dispatch is cost effective under the rule’s net benefits test, against the claim that it was arbitrary and capricious.
The companion 2016 decision drew the preemption side of the same line. Hughes v. Talen Energy Marketing, decided April 19, 2016, unanimously, struck down Maryland’s contract for differences program. Maryland had guaranteed a selected generator a fixed price for capacity so long as the generator cleared the PJM capacity auction, topping up or clawing back the difference between the contract price and the auction clearing price. Justice Ginsburg, writing for the Court, held the program preempted because it disregarded the interstate wholesale rate the commission requires. A state law that sets, or functionally sets, an interstate wholesale rate invades the commission’s exclusive domain. The Court limited its holding carefully. It did not address state measures to encourage generation untethered to wholesale market participation, such as tax incentives, land grants, direct subsidies, or state owned generation, so long as the state does not condition payment on capacity clearing the federally regulated auction. That limitation is as important as the holding. States retain broad authority to shape their generation mix through measures that do not touch the wholesale price; they lose only when they try to fix the price the wholesale market produces.
Two older decisions supply the foundation beneath the 2016 pair. Nantahala Power and Light v. Thornburg, 476 U.S. 953, decided in 1986, held that the commission’s allocation of power in wholesale interstate ratemaking preempts inconsistent state retail ratemaking. A state may not declare a commission approved wholesale rate unreasonable when it sets retail rates. The filed rate doctrine, as the principle is known, means the wholesale rate the commission approves is the rate the state must honor in the retail rate case. Mississippi Power and Light v. Mississippi ex rel. Moore, 487 U.S. 354, decided in 1988, extended the principle to state prudence reviews, holding that the Federal Power Act preempts state second guessing of wholesale cost allocations the commission has mandated, in that case the costs of the Grand Gulf nuclear plant. Together the four cases draw the line the way a practitioner needs it. The commission may regulate anything that directly affects the wholesale rate, states may not undo the wholesale rate at the retail meter, and states keep everything that does not touch the wholesale price.
The filed rate doctrine is the mechanism that connects the two layers. When the commission accepts a wholesale tariff, that tariff states the lawful wholesale rate, and the state commission setting retail rates must pass that wholesale cost through to retail customers rather than substituting its own judgment about what the wholesale rate should have been. Nantahala made that principle explicit: a state may not declare a commission approved wholesale rate unreasonable when it sets retail rates. In an ordinary retail rate case, therefore, the wholesale power cost is treated as a given, and the state proceeding focuses on the distribution costs, the allowed return on the utility’s own investment, and the allocation of costs among customer classes. The federal decision constrains the state decision without replacing it, which is the precise meaning of the floor in this field.
What the states do with their retained authority is extensive. State commissions run the retail rate cases that set the prices households pay. States site power plants through their own permitting regimes. States adopt the generation policies the Supreme Court in Hughes left untouched: tax incentives, land grants, direct subsidies, and state owned generation, all measures that encourage particular resources without conditioning payment on clearing the federally regulated wholesale auction. A state that wants more of a favored resource can pay for it directly; what the state cannot do is guarantee a generator a wholesale price different from the auction clearing price and then true up the difference. That is the operational meaning of the Hughes limitation, and state policymakers have spent the years since the decision designing programs that stay on the permitted side of it.
The D.C. Circuit’s role in drawing the line deserves attention because most commission orders are reviewed there. The directly affects construction that the Supreme Court adopted in the demand response case originated in the D.C. Circuit’s reading of the Federal Power Act’s affecting language, in California Independent System Operator v. FERC. The specialized bar that practices before the commission therefore reads D.C. Circuit decisions as the working law of jurisdiction, with Supreme Court review reserved for the cases where the circuit’s construction is challenged. The line thus has two authors: the circuit that refines it case by case and the Supreme Court that ratifies or corrects the refinement.
The floor and preemption framing is not unique to energy law. Federal law sets a floor and state law may build above it, until the state rule conflicts with the federal rate, and the same architecture governs other shared regulatory fields. The federal versus state labor protections guide walks through the general version of that architecture, and the energy version follows the same logic with higher stakes.
Why is the wholesale-retail line so difficult to draw?
Electricity flows on a single physical grid, so any rule aimed at wholesale prices changes retail bills and any rule aimed at retail service changes wholesale economics. The Supreme Court resolved the difficulty by asking whether a rule directly affects the wholesale rate, not whether it has any effect on it.
The jurisdiction and instrument table
The table is the findable artifact of this article. Each row names a subject, the decision maker, the statutory authority, the instrument the decision maker uses, and the route by which the decision can be reviewed.
| Subject matter | Who decides | Statutory authority | Instrument used | Review route |
|---|---|---|---|---|
| Interstate wholesale electricity sales | FERC | FPA sections 201, 205, 206; 16 U.S.C. 824, 824d, 824e | Filed tariffs, market rules, commission orders | Rehearing then U.S. courts of appeals under FPA section 313 |
| Interstate electricity transmission service | FERC | FPA sections 201, 205, 206 | Open access tariffs under Orders 888 and 889; regional planning under Order 1000 | Rehearing then courts of appeals under FPA section 313 |
| Retail electricity sales and local distribution | States | FPA section 201(b) exclusion; state law | State utility commission rate cases and tariffs | State courts under state law |
| Generation siting | States | FPA excludes generation facilities; state law | State siting permits and certificates | State courts under state law |
| Interstate gas transportation and wholesale sales | FERC | NGA sections 1(b), 4, 5; 15 U.S.C. 717, 717c, 717d | Filed tariffs, commission orders | Rehearing then courts of appeals under NGA section 19 |
| Local gas distribution and retail sales | States | NGA section 1(b) exclusion; state law | State commission rate cases | State courts under state law |
| Gas production and gathering | States | NGA section 1(b) exclusion | State regulation | State courts under state law |
| Interstate gas pipeline construction | FERC | NGA section 7(c) and 7(e); 15 U.S.C. 717f | Certificate of public convenience and necessity | Rehearing then courts of appeals under NGA section 19 |
| Condemnation for certificated pipelines | Certificate holder, in court | NGA section 7(h); 15 U.S.C. 717f(h) | Eminent domain action in district or state court | Federal appellate courts |
| Bulk power system reliability | FERC through the certified Electric Reliability Organization | FPA section 215; 16 U.S.C. 824o; EPAct 2005 section 1211 | Commission approved reliability standards developed by NERC | Enforcement review under FPA section 313 |
| Oil pipeline rates and practices | FERC | Interstate Commerce Act as frozen October 1, 1977; appendix to Title 49 | Filed tariffs, commission orders | Courts of appeals |
| Electric transmission siting | States, with federal backstop in designated corridors | State law; FPA section 216; 16 U.S.C. 824p | State permits; federal authorization in corridors | State courts; FPA section 313 for the federal backstop |
The table repays study because it shows the pattern the article keeps returning to. The commission decides at the wholesale and interstate layer through tariffs, orders, and standards, and those decisions are reviewed in the federal courts of appeals after the commission rules on rehearing. The states decide at the retail and local layer through their own commissions, reviewed in state court. The two rows where the layers touch, retail ratemaking that must honor the filed wholesale rate and state generation programs that must not fix the wholesale price, are where the litigation lives.
The Standard: Just and Reasonable
Every commission order ultimately rests on one statutory phrase. All rates and charges made, demanded, or received by any public utility for or in connection with the transmission or sale of electric energy subject to the jurisdiction of the commission, and all rules and regulations affecting or pertaining to such rates or charges, shall be just and reasonable, and any such rate or charge that is not just and reasonable is hereby declared unlawful. That is section 205(a) of the Federal Power Act, 16 U.S.C. 824d(a). Section 205(b) adds the anti discrimination command. No public utility shall make or grant any undue preference or advantage to any person or subject any person to any undue prejudice or disadvantage, or maintain any unreasonable difference in rates, charges, service, or facilities. Section 206(a), 16 U.S.C. 824e(a), gives the commission the enforcement half of the standard. If the commission finds that any rate, charge, or classification, or any rule, regulation, practice, or contract affecting such rate, charge, or classification, is unjust, unreasonable, unduly discriminatory, or preferential, the commission shall determine the just and reasonable rate to be thereafter observed and in force. The Natural Gas Act carries the parallel provisions in sections 4 and 5, 15 U.S.C. 717c and 717d.
The phrase did not originate with electricity. It came from railroad regulation. The Interstate Commerce Act of 1887 required railroad rates to be reasonable and just. The Hepburn Act of 1906 gave the Interstate Commerce Commission the express power to set maximum just and reasonable rates. Section 206(a) of the Federal Power Act mirrored section 15 of the Interstate Commerce Act. Congress carried the standard into energy law in the Federal Power Act, Title II of the Public Utility Act of 1935, and again in the Natural Gas Act of 1938, enacted June 21, 1938. The brief for this article described the phrase as inherited from 1930s ratemaking, and that is accurate as adoption history, but the full lineage runs one step further back, to the railroad era, which matters because it explains the standard’s design. It was built for monopoly rate regulation, for a world in which a single carrier served captive customers and the government set the price. The commission has spent eighty years applying that monopoly era phrase to competitive market design, and the stretching shows.
Section 205 and section 206 divide the commission’s ratemaking work into two postures. Under section 205 the utility files a new rate or a change to its tariff, and the commission reviews the filing to determine whether the proposed rate is just and reasonable. The utility bears the burden of supporting its proposal. Under section 206 the commission acts on its own motion or on complaint to investigate an existing rate or practice, and if it finds the rate unjust, unreasonable, or unduly discriminatory, the commission must prescribe the just and reasonable rate to be observed going forward. The two sections thus cover the two directions of regulatory traffic: the industry proposing and the commission disposing. Every market making order took the section 206 form. The commission found the existing practice, the closed transmission system, the absence of regional planning, to be unduly discriminatory, and it prescribed the new practice as the just and reasonable replacement.
The filed rate doctrine gives those determinations their binding force. Once the commission has accepted a tariff, the filed tariff is the exclusive lawful rate, and neither the utility nor the customer nor a state commission may depart from it. The doctrine serves two purposes. It prevents discrimination, because every similarly situated customer pays the filed rate rather than a negotiated one. And it protects the commission’s jurisdiction, because it denies state courts and state commissions a forum for second guessing the federal rate. Nantahala applied the doctrine against the states; the commission applies it against the industry every time it rejects a claim for a rate different from the tariff. For the practitioner the lesson is that the tariff is not paperwork. It is the law of the transaction.
In the monopoly era the commission gave the just and reasonable standard its content through cost of service ratemaking. The utility demonstrated its prudent investment and operating costs, and the commission allowed recovery of those costs plus a fair return on investment. The method suited a world of vertically integrated monopolies serving captive customers, and it dominated commission practice for the first four decades of the Federal Power Act. In the market era the commission gives the standard a different content. Where the commission has approved the structure of a competitive market, prices emerging from that market are treated as just and reasonable because the competitive process disciplines them. The commission therefore approves rate methodologies rather than rates: the auction rules, the bidding and mitigation provisions, the market power screens. A seller permitted to charge market based rates does so under a commission authorization that rests on findings about competitive conditions, and the authorization carries ongoing obligations. The standard is the same sentence in both eras. Its meaning changed because the industry it governs changed, and the commission changed the meaning through orders rather than waiting for Congress to amend the text.
How did a railroad rate phrase come to govern electricity markets?
Congress borrowed the just and reasonable standard from railroad regulation, where the Hepburn Act of 1906 gave the ICC express rate power, and installed it in the Federal Power Act of 1935. The commission later read that old ratemaking language as authority to approve market rules and auction designs.
Section 205(c), 16 U.S.C. 824d(c), supplies the filing mechanism that makes the standard operational. Every public utility must file with the commission schedules showing all rates and charges, the classifications, practices, and regulations affecting those rates, and all contracts that in any manner affect or relate to them. That filing duty is the filed rate doctrine in statutory form.
The phrase “affecting or pertaining to such rates or charges” is the jurisdictional engine of the entire statute, and it deserves close attention. Congress did not limit the commission to the rate itself; it extended the commission’s reach to every rule, regulation, practice, and contract that affects the rate. The demand response case turned on exactly that extension. The commission argued, and the Supreme Court agreed, that the practices of the organized wholesale markets in compensating demand response directly affect the wholesale rate, which placed them within the commission’s authority over practices affecting jurisdictional rates. The “affecting” language is thus the textual basis for the directly affects test: the statute grants jurisdiction over practices affecting rates, and the Court’s test distinguishes the direct effects the commission may regulate from the indirect effects it may not. Every market rule the commission has written, from the open access tariff to the capacity auction design, rests on the proposition that market structure affects rates and therefore falls within the statutory grant. The breadth of that proposition is what makes the commission powerful, and the directly affects limitation is what keeps the power bounded. Once a tariff is on file and accepted, it is the legal rate, and courts and state commissions must treat it as such. The commission’s real power over the electricity business therefore runs through the tariff. To approve a tariff is to set the rules of the market, and to order changes to a tariff is to redesign the market. Every market making order discussed below took the legal form of a change to filed tariffs, which is why the orders stick.
The standard’s vagueness is its power. Congress never defined just and reasonable, so the commission has defined it case by case across decades, and the courts have generally deferred to those definitions. In the monopoly era the definition meant cost of service ratemaking: the utility recovered its prudent costs plus a fair return. In the market era the definition means something different: rates produced by a competitive process the commission has approved are presumed just and reasonable because competition disciplines the price. That presumption is the legal foundation of market based rate authority, under which generators and marketers are permitted to sell at market prices rather than cost based rates, subject to commission findings that they lack market power or have mitigated it. The standard thus governs both the old world and the new one, which is why a single phrase can preside over multi billion dollar market designs without ever having been amended to mention markets.
The Market Making Orders
The modern American electricity market was not legislated. It was ordered. Four commission orders, issued between 1996 and 2011 under the 1935 just and reasonable standard, built the market architecture, and a 2016 notice of proposed rulemaking signaled where the next architecture might go. Each order resolved a specific problem, and the sequence shows the commission learning to govern by market design rather than by price setting. The sequence also shows the commission returning to the same statutory sentence for each new problem and finding in it a new grant of authority, which is why the orders read as a single extended interpretation of sections 205 and 206 rather than as four separate initiatives.
Order 888: Open Access
Order No. 888, issued April 24, 1996, and published at 61 Federal Register 21,540, required every transmission owner to offer open access transmission service on the same terms it gave itself. Before the order, a utility that owned transmission wires could favor its own generation, refusing or overpricing access for competing generators. The order’s remedy was functional unbundling: the utility had to separate its transmission function from its generation and marketing functions and take service under the same tariff it offered others. The vehicle was the pro forma open access transmission tariff, a standard tariff every jurisdictional transmission provider had to file, which standardized the terms of service across the industry. Order No. 889, issued the same day and published at 61 Federal Register 21,737, built the information infrastructure for open access: the Open Access Same Time Information System, the electronic bulletin board on which transmission providers post available capacity, and standards of conduct governing the separation of transmission and marketing personnel. Together the two orders converted the transmission grid from a private asset of vertically integrated utilities into a common carrier system, and every competitive electricity market in the country rests on that conversion.
The order’s legal theory was the anti discrimination half of the just and reasonable standard. Denying a competitor transmission access on the same terms the owner gave itself was, in the commission’s reading, an undue preference and an unreasonable difference in service between classes of customers. The remedy flowed from section 206. The commission found the existing practice unjust, unreasonable, and unduly discriminatory, and it prescribed the pro forma tariff as the just and reasonable practice to be thereafter observed. That is the template for every market making order that followed: find discrimination in the old practice, prescribe market design as the new practice.
The mechanics of functional unbundling show how the commission translates an anti discrimination finding into an operating regime. A transmission owner had to take service under its own open access tariff when moving its own generation, which meant its merchant arm stood in the same queue, paid the same rate, and received the same curtailment priority as an independent competitor. The standards of conduct policed the boundary: transmission personnel could not share nonpublic operating information with marketing personnel, and the OASIS postings made capacity availability visible to all market participants simultaneously. The design attacked discrimination at three points, the tariff terms, the information flow, and the personnel barrier, because discrimination in a network industry can travel through any of them. Later orders would reuse the three point method whenever the commission confronted a new form of preference.
The common carrier conversion had a consequence the commission understood and accepted. Once any generator could reach any customer over the open access grid, the generation business was contestable in a way it had never been. Independent generators could finance new plants against the prospect of selling into the open market rather than against a single utility’s long term contract. Marketers could assemble portfolios of supply without owning wires. The commission had not ordered competition in generation; it had ordered nondiscriminatory transmission, and competition in generation followed as the economic consequence. That pattern, in which the commission orders access and the market supplies the restructuring, recurs throughout the order sequence.
Order 2000: Regional Transmission Organizations
Order No. 2000, issued in December 1999 and published at 65 Federal Register 810, encouraged the formation of regional transmission organizations. The order did not mandate RTO membership; it set out the characteristics and functions an RTO should have and invited transmission owners to propose organizations meeting them. The characteristics included independence from market participants, an appropriate regional scope, operational authority over transmission facilities, and exclusive authority to maintain short term reliability. The functions included tariff administration and design, congestion management, parallel path flow management, ancillary services, OASIS administration, market monitoring, planning and expansion, and interregional coordination.
The order’s significance is structural. Open access under Order 888 was bilateral: a generator negotiated transmission service from each utility whose wires the power crossed. An RTO replaces that patchwork with a single regional operator that runs the transmission system, administers a single tariff, and operates the organized markets. The RTO is the institution that makes the auction possible. The commission’s encouragement worked. By the mid 2000s, RTOs and independent system operators covered roughly two thirds of the country’s electricity load, and the organized markets they run, day ahead and real time energy auctions, capacity auctions, and ancillary service markets, became the price discovery mechanism for wholesale electricity across most of the country. The order also illustrates the commission’s characteristic method: rather than commanding a structure, the commission defined a model and used the carrot of regulatory approval to pull the industry toward it.
The eleven characteristics and functions the order specified repay attention because they define what a regional operator actually does. Independence from market participants prevents the operator from favoring its own commercial interests. Regional scope ensures the operator sees enough of the grid to manage flows that cross utility boundaries. Operational authority means the operator, not the individual utility, directs the transmission system in real time. The functions then layer the markets on top of the operations: a single regional tariff replacing the pancaked bilateral tariffs, congestion management pricing the scarce capacity, market monitoring watching for manipulation and market power, and planning identifying the transmission expansion the region will need. Each function answers a problem that bilateral open access left unsolved, which is why the order reads as the second volume of the work Order 888 began.
The voluntary design was a calculated choice. A mandate to join RTOs would have provoked a jurisdictional and political fight the commission preferred to avoid, and the commission judged that the efficiency gains of regional operation would pull transmission owners in without compulsion. The judgment largely held in the eastern and midwestern grids, where regional operators came to administer the organized markets, while other regions retained bilateral markets under the open access tariffs. The resulting map, part organized markets and part bilateral trading, is the product of that voluntary architecture. The commission governs both parts, but it governs them through different instruments: the RTO tariff and market rules in the organized regions, the pro forma open access tariff in the bilateral ones.
Order 745: Demand Response
Order No. 745, issued March 15, 2011, and published at 76 Federal Register 16,676, required organized wholesale markets to pay demand response resources the full locational marginal price when dispatching demand response is cost effective. Locational marginal price is the price of the next increment of electricity at a given location on the grid; it reflects generation cost, congestion, and losses. The rule’s net benefits test screened out cases where paying demand response the full price would not actually lower costs to consumers. The commission’s theory was comparability. A megawatt of reduced demand and a megawatt of generated supply do the same work on the grid, so compensating them differently discriminates against the demand side. The order thus extended the open access logic from transmission wires to the demand side of the market.
The order drew the jurisdictional challenge that produced the Supreme Court’s directly affects test. Opponents argued that paying retail consumers to reduce consumption regulated retail sales. The commission answered that it was regulating the wholesale market’s compensation practices, which directly affect the wholesale rate. The Court agreed, six to two, in the 2016 decision discussed above. The episode shows the full cycle of commission lawmaking at work. The commission identifies a barrier to competition, writes a market rule to remove it, defends the rule’s jurisdictional basis in court, and the court’s decision becomes the new jurisdictional precedent for the next rule.
The net benefits test was the commission’s answer to the obvious objection. Paying a consumer the full market price for not consuming electricity looks like a subsidy unless the payment actually lowers total costs. The test screens each dispatch: demand response is paid the full locational marginal price only when dispatching it reduces the cost of serving load, which occurs when the demand reduction displaces generation whose cost exceeds the price effect of the reduced demand. In plain terms, the commission pays for negawatts only when the negawatts are cheaper than the megawatts they replace. The test made the rule an efficiency measure rather than a transfer, and it gave the Supreme Court a concrete economic mechanism to point to when it held that demand response directly affects the wholesale rate.
The litigation arc is as instructive as the rule. The court of appeals set Order 745 aside, holding that the commission had crossed into retail regulation. The Supreme Court reversed, six to two, adopting the directly affects test and holding that wholesale market compensation of demand response satisfies it. The reversal did more than save one rule. It supplied the jurisdictional test the commission now uses to defend every market rule that touches the demand side, and it confirmed that the commission may regulate the wholesale market’s treatment of a resource even when that resource sits behind a retail meter. The three part reasoning, direct effect on the wholesale rate, no compulsion of state retail policy, consistency with the act’s consumer protective purposes, is the template for the commission’s jurisdictional defense in the next dispute.
Order 1000: Planning and Cost Allocation
Order No. 1000, issued July 21, 2011, and published at 76 Federal Register 49,842 as 136 FERC paragraph 61,051, addressed the long term problem the earlier orders left unsolved: who plans transmission for the region, and who pays for it. The order required transmission providers to participate in regional planning processes that consider transmission needs driven by public policy requirements, to coordinate with neighboring regions, and to adopt methods for allocating the costs of new transmission facilities. It also removed the federal right of first refusal from commission jurisdictional tariffs, opening the construction of regional transmission projects to competitive bidding by non incumbent developers.
The cost allocation principle the order adopted was beneficiary pays: costs should be allocated roughly commensurate with benefits. That principle sounds obvious and is operationally difficult, because the benefits of a transmission line, lower congestion costs, improved reliability, access to cheaper generation, access to renewable resources required by state policies, spread across many parties over decades. The order did not dictate a single allocation method; it required each region to adopt a method satisfying the commission’s principles and to defend it in a tariff filing. The result was a new layer of regional governance, the planning process, alongside the operational layer of the RTO and the service layer of the open access tariff.
The order sequence from 888 to 1000 traces an arc. Open the wires, organize the region, price the demand side, plan the future grid. At each step the commission acted under the same statutory sentence about just and reasonable rates, and at each step the courts sustained the reading that market design is ratemaking. The sequence is also the answer to the question of where American electricity market structure came from. It came from 888 H Street, the commission’s headquarters, not from the Capitol.
The public policy requirement was the order’s most consequential planning innovation. Transmission planners had traditionally built for reliability and economics: keeping the lights on and relieving congestion. Order 1000 required them also to consider transmission needs driven by public policy requirements, which in practice meant the state laws that mandate particular generation resources. A state that subsidizes favored generation through the untethered measures Hughes permits, direct payments and tax incentives rather than wholesale price guarantees, still needs wires to move that generation to load. The order made the regional planning process the forum where those needs are identified and the beneficiary pays principle the method for assigning their costs. The federal planning rule thus became the transmission complement to state generation policy, which is one more illustration of how the wholesale retail boundary is managed rather than eliminated.
Removing the federal right of first refusal changed who builds. Before the order, the incumbent utility that owned the regional grid had the first right to build new regional transmission projects in its footprint. The order stripped that preference from jurisdictional tariffs, requiring competitive solicitation for regional projects so that independent developers could propose, finance, and build transmission. The commission’s theory was the familiar one: the incumbent’s preference was an undue advantage, and competition in development would produce better projects at lower cost. Incumbent utilities challenged the removal, and the courts sustained it, which extended the open access principle from the use of existing wires to the construction of new ones. The interregional coordination requirement completed the design by obliging neighboring planning regions to share data and identify efficient cross border projects, addressing the seam problem where regional plans meet.
The commission’s rulemaking instrument for the next steps was the notice of proposed rulemaking. On November 17, 2016, the commission issued a notice proposing to remove barriers to electric storage resources and distributed energy resource aggregations in the organized markets. A notice of proposed rulemaking is a proposal, not a rule; it invites comment and commits the commission to nothing. It had produced no final order by December 15, 2016, and the article treats it only as an illustration of the instrument, the commission signaling the next market design problem it intended to take up.
Did Congress design the wholesale electricity markets that operate in the United States?
Congress did not. The statutes authorize the commission to ensure just and reasonable rates, but the market structures, the regional transmission organizations, the auction designs, the planning regions, were created by commission orders interpreting that phrase. The most consequential energy policy of the last thirty years was made by an agency exercising ratemaking authority, not by Congress designing markets.
Orders, Not Statutes: The Namable Claim
The structure of American electricity markets was built almost entirely by commission orders issued under a 1935 phrase about just and reasonable rates. That sentence is the namable claim of this article, and it carries the series thesis at its widest point: the gap between statutory text and delivered policy. Congress wrote a ratemaking standard for monopoly utilities. The commission turned it into the legal basis for competitive markets, open access, regional organizations, demand response compensation, and regional transmission planning. The most consequential energy policy of the last thirty years was made by an agency exercising ratemaking authority rather than by Congress legislating market design.
The claim is not that Congress was absent. Congress wrote the jurisdictional sentence, the standard, and the filing requirement, and in 2005 it added reliability and expanded enforcement. But Congress never designed a market. It never specified an auction, a tariff, or a regional organization. The commission did all of that, and the reason the arrangement is lawful is that the courts have read market design as an application of the just and reasonable standard rather than as legislation. The deference the courts give the commission on what the standard means is the hinge of the entire system. So long as the commission can explain why a market rule produces just and reasonable rates, the rule stands.
That deference has a structure worth naming. The courts do not defer to the commission’s policy preferences; they defer to its reasoned application of the statutory standard to the record before it. When the commission found transmission discrimination and prescribed open access, the courts asked whether the finding was supported and the remedy reasonably related to it, and they sustained both. When the commission compensated demand response at the market price, the Court asked whether the practice directly affected the wholesale rate and whether the compensation method was arbitrary, and it sustained both. The pattern is consistent: the commission earns deference by building the record, and the record is the thousand page accumulation of comments, technical conferences, and economic analysis that each major rule carries. Deference is thus not a blank check but a reward for procedure, which returns the argument to the commission’s characteristic strength. It governs through instruments whose design can be defended, and the defense is what makes the instruments law.
That arrangement has a democratic cost that the article should name plainly. Market design decisions move billions of dollars among generators, consumers, and states, and they are made by five unelected commissioners through technical orders that few citizens read. The commission’s answer to that concern is procedural: notice and comment rulemaking, public technical conferences, reasoned orders, and judicial review. Whether that answer satisfies is a question for the reader.
The deeper point is about how American government actually legislates in technical fields. Congress writes the jurisdictional sentence and the standard, the agency writes the operating system, and the courts patrol the boundary between them. The pattern is not unique to energy; it is the standard form of the modern administrative state. What makes the commission’s version the widest gap in this series is the thinness of the starting text relative to the thickness of the resulting system. A single sentence about just and reasonable rates supports an entire market architecture that no legislator in 1935 described, debated, or voted on. The article’s function is to make that architecture legible, so that debates about electricity policy can be debates about the actual mechanism rather than about slogans.
Pipeline Certificates
Why is a pipeline certificate the commission’s most contested instrument?
A pipeline certificate is the only commission instrument that takes private land. It confers federal eminent domain under section 7(h) of the Natural Gas Act, drawing landowners, environmental litigants, and state officials into a single docket where property rights, energy need, and environmental review are decided together, and that concentration of stakes makes every major certificate politically contested.
The commission’s most politically contested function is also its oldest in form. Section 7(c) of the Natural Gas Act, 15 U.S.C. 717f(c), provides that no natural gas company may engage in jurisdictional transportation or sale, or construct, extend, or operate jurisdictional facilities, without a certificate of public convenience and necessity issued by the commission. Section 7(e), 15 U.S.C. 717f(e), states the issuance standard. The applicant must show that it is able and willing to do the acts and perform the service proposed, and the commission must find that the proposed service, sale, operation, construction, extension, or acquisition is or will be required by the present or future public convenience and necessity.
The phrase “present or future” does quiet work in that standard. It authorizes the commission to certificate capacity for demand not yet in existence when the application is filed but reasonably projected, which is why pipelines can be built ahead of load growth rather than only in response to it. The forward looking element also explains why the need determination relies on long term precedent agreements: a shipper’s twenty year commitment is evidence of future need that no snapshot of existing flows could supply. The commission’s balancing thus has a temporal dimension missing from ordinary rate cases. It judges not only whether the project serves the market of the application year but whether it will serve the market the commission expects, and challengers attack the projection as readily as they attack the showing of existing need. The commission applies that standard through a public interest balancing that weighs the need for the project, usually demonstrated through contracts for capacity or market studies, against its adverse effects on captive customers, existing pipelines and their customers, the environment, and landowners.
The certificate is the commission’s siting power, and it is nearly the commission’s only siting power. The commission does not site power plants, wind farms, or solar arrays; the states do. But for interstate gas pipelines the certificate is the federal permission that makes construction lawful, and the certificate proceeding is the forum in which the project’s need, its route, its environmental impact, and its landowner effects are all adjudicated. That concentration of decision making in a single proceeding is what makes certificate cases the commission’s most contested docket. Every interested party, the applicant, competing pipelines, customer groups, state agencies, environmental organizations, and landowners, intervenes in the same case, and the commission must weigh their claims against the statutory standard.
The application itself is a substantial engineering and commercial document. It describes the pipeline’s route, diameter, capacity, compression, and interconnections; it presents the market analysis supporting the claimed need; and it includes the environmental resource reports that feed the staff’s NEPA review. Intervention is freely available to interested parties, which is why certificate dockets accumulate hundreds of intervenors. The commission’s staff then develops the environmental record while the commission evaluates the commercial record, and the two tracks merge in the certificate order. Conditions attached to the grant can reshape the project: route modifications, construction timing restrictions to protect wildlife, noise limits at compressor stations, and ongoing environmental compliance monitoring. A certificate is therefore rarely a simple yes; it is a yes with a detailed operating code.
The commission’s stated standard for the need determination has two poles.
The commission’s stated standard for the need determination has two poles. On one side, precedent agreements, long term contracts in which shippers commit to buy capacity, are the strongest evidence that the market wants the pipeline. On the other side, the commission examines whether existing capacity could serve the same need and whether the project would harm captive customers of existing pipelines. Environmental review runs on a parallel track within the same proceeding and is addressed in the next section. The balancing is qualitative, not formulaic, which is why certificate orders run to hundreds of pages and why disappointed parties seek judicial review as a matter of course.
The review route is rehearing before the commission followed by the courts of appeals under section 19 of the Natural Gas Act. Courts review the commission’s need determination under the deferential arbitrary and capricious standard, and they sustain the certificate when the commission has built an adequate record. The legal posture of a certificate challenge is therefore an attack on the record: the challenger argues the commission ignored evidence, misweighed the balancing, or failed to take the hard look the environmental statutes require. The commission’s defense is the record itself.
What does a pipeline certificate proceeding look like?
The applicant files for a certificate, the commission opens a docket, interested parties intervene, staff conducts environmental review, and the commission issues an order granting or denying the certificate with conditions. Landowners, states, and environmental groups participate as intervenors and may seek rehearing and appellate review.
Eminent Domain
A certificate of public convenience and necessity carries the power of eminent domain. Section 7(h) of the Natural Gas Act, 15 U.S.C. 717f(h), added in 1947, provides that a certificate holder unable to acquire necessary rights of way by contract may acquire them by exercising the right of eminent domain in the district court of the United States for the district where the property is located, or in the state courts. The provision makes the commission’s certificate the legal foundation for condemning private land for a private pipeline company’s project, which is why the certificate function draws the intensity it does.
The eminent domain authority belongs to the certificate holder, not to the commission. The commission decides whether the project serves the public convenience and necessity; the company then negotiates with landowners, and only when negotiation fails does it file condemnation actions. Compensation is determined in the condemnation proceeding, not by the commission.
The negotiation stage matters more than the condemnation stage in practice, because most rights of way are acquired by agreement. The certificate holder approaches each landowner with an offer, and the landowner may accept, negotiate for better terms, or refuse and force the condemnation action. The company’s leverage in the negotiation is the certificate itself: the landowner knows the company can condemn, which shapes the bargaining. Landowner advocates argue that this dynamic makes the negotiation coercive in substance even when it is voluntary in form, because the fallback is a court proceeding the company is certain to win on the question of authority. The company’s answer is that the compensation proceeding protects the landowner’s economic interest and that negotiated agreements routinely exceed what a court would award. The statute gives the landowner the choice of forum for the condemnation, federal district court or state court, but not the choice of whether condemnation occurs. That allocation, authority to the certificate and compensation to the courts, is the 1947 settlement, and every eminent domain fight since has been fought within it. Losing the first fight does not end the second, but it narrows it, because the court in the condemnation case does not revisit the commission’s public convenience determination.
The arguments around certificate related eminent domain divide along predictable lines, and the article presents them with equal care. Project supporters, including the applicant and often the gas producers and consumers the pipeline would serve, argue that the pipeline is needed to move gas from supply to demand, that negotiated acquisition resolves most parcels, and that eminent domain is a last resort governed by judicial compensation proceedings. They emphasize that the certificate itself is the product of the public convenience finding, so the condemnation that follows rests on a federal determination of public need rather than on private preference. Landowner advocates argue that the condemnation power should not be available for a private company’s commercial project, that the compensation process undervalues land and ignores nonmarket harms such as the disruption of farming operations and the division of parcels, and that the certificate standard sets the bar for need too low by crediting the applicant’s own precedent agreements. Environmental commenters argue that the climate effects of the gas the pipeline would carry should weigh more heavily in the public convenience determination, and that the current balancing understates those effects. State and local officials argue about the distribution of costs and benefits across their jurisdictions, with producing and consuming regions seeing the gains differently from the transit regions that host the pipe. The commission’s stated position is that it applies the statutory standard, weighs the evidence in the record, and conditions certificates to mitigate adverse effects. The article takes no position among these claims; its function is to show where each claim is adjudicated and under what standard.
Environmental Review of Certificates
Every certificate proceeding carries an environmental review under the National Environmental Policy Act. The commission is the lead federal agency for that review. The Energy Policy Act of 2005, in section 313(b), designated the commission as the lead agency coordinating NEPA compliance and all federal authorizations for pipeline projects. In practice the commission’s staff prepares an environmental assessment for most projects and an environmental impact statement where impacts may be significant, and for major pipeline and LNG terminal applications the commission generally prepares full impact statements. The review examines the project’s direct, indirect, and cumulative effects, considers alternatives including the no action alternative, and responds to public comment. The certificate order incorporates the review’s findings and typically attaches environmental conditions, such as construction mitigation measures, that the certificate holder must satisfy.
The NEPA review is the second litigation front in certificate cases, alongside the need determination. Challengers argue the commission’s environmental analysis was inadequate: that it understated greenhouse gas effects, failed to consider downstream combustion of the transported gas, ignored a reasonable alternative route, or segmented its review to avoid confronting cumulative impacts. The commission’s defense is again the record: the scope of the analysis, the alternatives considered, and the responses to comments. Courts apply the rule of reason to NEPA claims, asking whether the agency took the required hard look, not whether it reached the right conclusion.
The lead agency designation gives the NEPA review its coordinating power. Because the commission manages the environmental review for all federal authorizations connected to the project, the other federal agencies with permitting roles, such as the Army Corps of Engineers for water crossings, participate as cooperating agencies in the commission’s process rather than running separate reviews on separate timelines. The design compresses what could be a sequence of agency reviews into a single proceeding with a single record, which is why the certificate order can address the project’s full federal footprint. For major pipeline and LNG terminal applications the commission generally prepares full environmental impact statements, the most searching form of NEPA review, with scoping, draft publication, public comment, and a final statement responding to the comments received. The environmental impact statement guide treats the NEPA instrument in full; the certificate context is where the commission most often defends it.
A recurring misunderstanding deserves correction. Pipeline approval is not an environmental decision in the sense that environmental harm alone defeats a certificate. The commission’s task under section 7 is the public convenience and necessity balancing, and the NEPA review informs that balancing without dictating its outcome. A project with significant environmental effects can be certificated with mitigation if the commission finds the need outweighs the harm, and a project with modest effects can be denied if the need is not shown. Environmental groups that treat the certificate proceeding as a referendum on fossil fuels and applicants that treat NEPA as a paperwork exercise both misread the legal structure. The structure is a balancing test informed by environmental analysis, and the litigation tests whether the balancing was reasoned.
Oil Pipelines: The Frozen Statute
The commission also regulates oil pipelines, and the authority for that function has the strangest statutory form in the commission’s portfolio. Oil pipeline regulation began with the Hepburn Act of 1906, which brought oil pipelines under Interstate Commerce Commission rate regulation. The Department of Energy Organization Act transferred that authority to the commission effective October 1, 1977, through sections 306 and 402(b), codified at 42 U.S.C. 7155 and 7172(b). In 1978 Congress partially repealed and recodified the Interstate Commerce Act, but section 4(c) of Public Law 95-473 provided that the repealed portions remain in effect as they existed on October 1, 1977, to the extent they relate to the movement of oil by pipeline and the rates and charges for that movement. The applicable law is therefore the Interstate Commerce Act as frozen on October 1, 1977, printed as an appendix to Title 49 of the United States Code, and the current code’s transfer machinery sits at 49 U.S.C. 60501 through 60503.
The brief for this article described the authority as the Interstate Commerce Act, and the verifier corrected that phrasing: the live statute is the frozen version, not the act as a current codification. The distinction matters in practice because it fixes the substantive law at its 1977 content. The commission applies the old act’s just and reasonable and anti discrimination standards to oil pipeline tariffs, using ratemaking methods developed for that industry, including indexed rate ceilings that allow annual adjustments tied to an inflation based index.
The index method shows how the commission adapts old law to a changing industry without new legislation. Rather than litigating the cost of service of every pipeline in every rate case, the commission permits pipelines to adjust rates annually within a ceiling tied to a published inflation index, with shippers free to challenge the indexed rate if they can show it exceeds just and reasonable levels. The method trades precision for administrability: it keeps rates roughly aligned with costs across the industry while avoiding the expense of perpetual cost of service litigation. A pipeline that wants to charge above the ceiling must file a cost of service justification; a shipper that believes the ceiling is too generous may file a complaint under the act’s complaint procedures. The frozen statute thus supports a living ratemaking practice, which is the commission’s characteristic move in miniature.
The transfer machinery in the current code, at 49 U.S.C. 60501 through 60503, allocates the old Interstate Commerce Commission functions between the Secretary of Energy and the commission, with the commission receiving the rate regulatory functions. The oil pipeline function is quieter than the electric and gas functions, but it governs the rates for the pipelines that move crude oil and refined products across the country, and its frozen statute is a reminder that the commission’s authority is an accumulation of historical transfers rather than a single coherent grant.
Reliability: From Voluntary Practice to Enforceable Law
Until 2005, the reliability of the bulk power system rested on voluntary compliance. The North American Electric Reliability Corporation developed reliability standards, and utilities followed them because the physics of the grid demanded coordination, not because the law required it. The Energy Policy Act of 2005 changed that. Section 1211 of the act added section 215 to the Federal Power Act, 16 U.S.C. 824o, creating a system of mandatory, enforceable reliability standards under the commission’s oversight.
The voluntariness of the old regime was its structural weakness. A standard that binds only those who choose to follow it cannot discipline the free rider, the entity whose noncompliance imposes costs on the interconnected system while capturing the benefits of everyone else’s compliance. On an interconnected grid, one entity’s failure to maintain adequate reserves or to coordinate its protection systems can cascade across utility boundaries, which means reliability is a collective good that voluntary compliance underprovides. Congress’s judgment in 2005 was that the physics required a legal backstop: the standards would remain technically authored by the industry, but compliance would become a legal duty enforceable by the commission. The mandatory regime thus solved the collective action problem that voluntarism could not, by attaching penalties to the practices the engineers had already identified as necessary.
The statute’s design delegates the drafting to industry and reserves approval and enforcement to the commission. Section 215 directs the commission to certify an Electric Reliability Organization that develops proposed standards through an open process, and the commission approves, remands, or directs modification of the proposed standards. A standard becomes enforceable only when the commission approves it. The commission certified NERC as the Electric Reliability Organization in July 2006, after issuing Order No. 672 in February 2006 to establish the certification and standard approval rules. In Order No. 693, issued March 16, 2007, the commission approved 83 of the 107 standards NERC had proposed, directing work on the remainder. Both monetary and nonmonetary penalties may be imposed for violations of approved standards, which converted what had been industry best practice into federal law backed by fines.
The open development process is what legitimates the delegation. NERC drafts standards through committees with balanced representation from the industry segments that must live under them, transmission owners, generators, distributors, and marketers, and any interested party may participate and comment. The commission’s review then tests the proposal against the statutory criteria: whether the standard is just, reasonable, not unduly discriminatory, and in the public interest. When the commission remands a standard or directs modification, it sends the drafting body back to work with instructions, preserving the industry’s technical authorship while asserting the regulator’s legal authority. The arrangement has drawn criticism from both directions. Industry participants argue that commission directed modifications second guess engineering judgment; reliability advocates argue that the process moves too slowly when new risks emerge. The commission’s answer is the record of approvals: standards covering operations, planning, cybersecurity practices for control systems, and emergency preparedness now carry the force of law across the bulk power system.
The reliability function completes the commission’s portfolio and illustrates its characteristic posture. The commission does not write the reliability standards itself; it judges them, approves them, and enforces them.
Compliance with the approved standards runs through self reporting, audits, and investigations. Registered entities report violations they discover, the Electric Reliability Organization conducts compliance audits on a cycle, and violations can draw monetary penalties scaled to the seriousness of the lapse and nonmonetary remedies such as mitigation plans. The penalty structure serves the same function as the tariff in the market context: it makes the standard’s obligations concrete enough that the industry invests in compliance systems rather than treating the standards as aspirations. The commission’s oversight of the compliance program, including review of penalty determinations, keeps the enforcement consistent across regions while leaving the technical monitoring to the organization that wrote the standards. The conversion the 2005 act accomplished is thus complete at three levels: the standards are mandatory in law, monitored in practice, and penalized in enforcement. The technical content comes from the industry organization, the legal force comes from the commission’s approval, and the enforcement runs through commission proceedings subject to judicial review. The arrangement reflects a congressional judgment that the engineers should write the rules and the regulator should make them stick.
The statutory framework for all of this, the sequence of energy statutes from the postwar period through the 2005 act, is mapped in the series’ energy legislation survey, which places the commission’s authorities in chronological order.
The Complication: The Commission Does Not Set Your Electric Bill
The most common misunderstanding about the commission is that it sets electricity prices. It does not. The commission approves tariffs, market rules, and rate methodologies. In the organized markets, prices are set by auction under rules the commission has approved. The distinction is not a technicality; it is a different and more interesting form of authority.
The misunderstanding persists because the commission’s authority over the rules is so complete that it can look like authority over the prices. When the commission changes the auction’s demand curve, the clearing price moves; when it changes the mitigation rules, the offers move; when it changes the capacity requirement, the quantity procured moves. Every design choice has price consequences, which tempts observers to describe the commission as setting prices through the back door. The commission’s answer, sustained by the courts, is that governing the conditions of price formation is the statutory job Congress assigned: the just and reasonable standard commands the commission to ensure the rates are lawful, and in a market regime the way to do that is to ensure the market is workably competitive. The price is the market’s output; the commission’s output is the market.
The auction mechanics are easiest to see in the capacity market the Supreme Court described in Hughes. Sellers of capacity bid into the PJM auction. PJM accepts bids in ascending price order until projected demand is met. Every accepted seller receives the clearing price, the price of the highest accepted bid. The commission does not choose that price. It regulates the structure of the auction, the bidding rules, the market power mitigation, the demand curve, to ensure the auction balances supply and demand efficiently and produces a just and reasonable clearing price. The commission’s authority is therefore architectural. It designs the building; the market sets the rent.
The same architecture governs the energy auctions. Generators offer supply at prices reflecting their costs, the market operator dispatches the cheapest combination that meets demand subject to transmission constraints, and the locational marginal price at each point on the grid is the result. The commission’s orders set the rules for offer caps, for mitigation of market power, for the treatment of demand response and other resources, and for the transparency of the process.
Market power mitigation is where the architectural authority meets its hardest test. In a competitive auction no single seller can profitably raise the price, but in the concentrated conditions that occur on parts of the grid, a pivotal supplier might withhold capacity or bid above cost to move the clearing price. The commission’s market rules therefore include mitigation provisions that cap the offers of sellers found to have market power in defined circumstances, replacing their bids with cost based reference levels. The mitigation rules are themselves commission approved tariff provisions, challengeable through the same rehearing and appellate review as any other tariff term. When prices spike, the commission’s question is not whether the price was too high in some absolute sense but whether the market rules functioned as designed and whether any participant exercised market power the rules were meant to constrain. That is a very different inquiry from price setting, and it requires a very different expertise: the economics of auction design rather than the accounting of cost of service.
Retail pricing stays with the states. The state utility commission sets the retail rate the household pays, and under the filed rate doctrine it must honor the wholesale costs the commission has approved. A consumer angry about a high electric bill is therefore looking at a state decision built on top of a federal market design. Both layers matter, and blaming the wrong layer is the standard error in public debate about electricity prices.
Enforcement Posture and the Compliance Architecture
The commission enforces its orders through a compliance architecture that regulated parties navigate daily. Public utilities file tariffs under section 205 and may charge only the filed rate. Sellers seeking market based rate authority file applications demonstrating they lack market power or have mitigated it, and they accept ongoing reporting obligations and codes of conduct. Transmission providers operate under their open access tariffs and the standards of conduct that separate transmission operations from marketing. Pipeline companies operate under certificates with environmental and service conditions. Reliability entities comply with the approved standards and face penalties for violations.
The common thread is that the commission governs less through after the fact punishment than through the design of the instruments. The tariff, the certificate, and the reliability standard each embed the compliance obligation in the authorization to do business: to hold the authorization is to accept the duties it states. A jurisdictional seller that departs from its filed tariff violates the filed rate, not some free floating duty of good behavior. A pipeline that ignores a certificate condition violates the certificate. A reliability entity that misses a standard violates the standard. Enforcement then polices the boundary of the instrument rather than inventing new duties case by case, which is why commission compliance practice centers on the precise language of tariffs, certificates, and standards. The industry’s compliance investment, the tariff administration departments, the codes of conduct, the training programs, the internal surveillance, is the visible evidence of that instrument centered design.
The enforcement docket reflects the commission’s institutional character rather than any administration’s politics. Investigations arise from market monitoring referrals, from audits, from complaints, and from the commission’s own surveillance. Settlements resolve most cases. Contested enforcement actions proceed through administrative process with judicial review available. The commission’s penalty authority, expanded in 2005, gives its enforcement office leverage that the pre 2005 commission lacked, and the industry’s compliance investment, the tariffs, the codes of conduct, the training programs, the internal surveillance, is the visible evidence of that leverage.
For students working through the jurisdictional line and the order sequence, which are standard examinable material in energy and administrative law coursework, a legislation study notebook offers a structured place to brief each order against the statutory provision it applied. The broader civics context for the federal state division of authority is covered in a US government civics study that maps how concurrent jurisdiction works across regulatory fields.
How the Commission Makes Rules: The Rulemaking Instrument
The notice of proposed rulemaking is the commission’s principal lawmaking instrument, and its mechanics explain how the market orders came into being. The commission issues a notice describing the problem it has identified, the rule it proposes, and the legal basis for acting. Interested parties file comments, typically in the hundreds, and reply comments responding to one another. The commission frequently convenes technical conferences where staff, industry engineers, economists, and advocates test the proposal against operating reality. The commission then issues a final rule that must respond to the significant comments, explain its choices, and ground each provision in the statutory authority. Parties aggrieved by the final rule seek rehearing, and the commission’s rehearing order refines or defends the rule before it goes to the courts of appeals.
How does a tariff become law without Congress voting on it?
Congress voted once, in 1935, to require that all jurisdictional rates and the rules affecting them be just and reasonable. Every tariff the commission approves applies that standing instruction. The commission judges each filing against the 1935 standard, and an approved tariff carries the force of law because the statute makes the commission the final interpreter of the standard.
The November 17, 2016 notice on electric storage and distributed energy resource aggregations illustrates the instrument at the proposal stage. The notice identified barriers that kept storage resources and aggregated distributed resources from participating fully in the organized markets, proposed tariff changes to remove them, and invited comment. As a proposal it committed the commission to nothing; the notice and comment process would determine whether, and in what form, a final rule emerged. The article treats the notice only in that posture, as an example of how the commission signals the next market design problem, because the commission had issued no final rule on the subject by December 15, 2016.
Softer instruments fill the space around rulemaking. Policy statements announce how the commission intends to exercise its discretion without binding it. Notices of inquiry invite comment on whether a rulemaking is needed at all. Declaratory orders resolve legal uncertainty for a particular party or practice. Guidance documents and staff white papers shape expectations without the force of law. The practitioner learns to read the full spectrum, because the commission often signals a coming rulemaking through a policy statement or a technical conference long before the notice issues. The orders that built the modern market all traveled this path from signal to proposal to final rule, which is why the commission’s agenda is legible to those who watch the instruments rather than the headlines.
Inside the Tariff: Where the Market Rules Live
The tariff is an unusual legal instrument: a private company’s filing that becomes public law upon approval. Understanding what lives inside a modern tariff is understanding how the commission governs without issuing a new order for every decision. The pro forma open access transmission tariff required by Order No. 888 is the template. Every transmission provider’s tariff offers the same categories of service on the same terms, with the provider’s own use of the system treated identically to a competitor’s. The schedules define the products, the business practices define how capacity is requested and scheduled, and the rate schedules define what each product costs. A transmission customer that wants to move power across a utility’s system does not negotiate a bespoke contract. It takes service under the tariff, and the tariff’s comparability is the legal guarantee that the owner’s own generation gets no better deal.
The regional transmission organization tariff is larger by an order of magnitude. It contains the market rules for the energy markets, in which generators offer supply and load serving entities bid demand for each hour, with prices set at each location reflecting the marginal cost of serving the next increment of load including the effects of transmission congestion. It contains the capacity market rules, in which the auction described in the Hughes syllabus procures enough generation to meet projected peak demand plus a reserve margin, with every accepted seller receiving the clearing price. It contains the market power mitigation rules, which screen bids for the exercise of market power and cap them when a seller is pivotal, meaning the market cannot clear without its supply. It contains the settlement rules, which turn auction results into invoices, true up differences between day ahead commitments and real time operations, and allocate the uplift costs that arise when the operator must take out of market actions to keep the system reliable.
Each of these components was approved by the commission as just and reasonable, and each can be challenged under section 206 as unjust or unreasonable when conditions change. The mitigation rules illustrate the dynamic. A bidding cap set at an appropriate level prevents the exercise of market power. The same cap set too low discourages investment in new generation, because investors cannot earn the scarcity revenues that justify building. Set too high, it permits sellers to extract rents from captive load. The commission’s task in approving mitigation is to find the level that disciplines market power without destroying investment incentives, and the record in a mitigation proceeding is full of competing economic models. There is no formula in the statute for the right cap. There is only the standard, just and reasonable, applied to the evidence about how the market actually behaves.
The settlement rules illustrate a different facet of tariff law. Electricity markets settle in two stages: a day ahead market in which participants commit to buy and sell for each hour of the next day, and a real time market that balances the differences between those commitments and actual operations. The tariff defines how deviations are priced, how congestion revenues are distributed, and how the costs of operator interventions are allocated. These are the plumbing of the market, invisible to the public but determinative of who pays for what. A generator that clears in the day ahead market and then fails to perform in real time faces settlement charges defined by the tariff. A load serving entity whose actual consumption exceeds its day ahead purchase pays the real time price for the difference. The commission approved every one of these mechanics as part of the market design, and disputes about them are tariff interpretation disputes decided by the commission in the first instance.
Credit and collateral requirements, the financial backstop of the markets, show how far tariff authority reaches into commercial practice. Market participants must post collateral to cover their potential settlement obligations, because a default by one participant becomes a cost to the others. The tariff sets the collateral formulas, the cure periods, and the consequences of default. These provisions look like private commercial terms, but they are commission approved and commission enforceable, because the financial integrity of the market affects the rates everyone pays. The tariff is thus not only a price list. It is a commercial code for the wholesale electricity business, written by market operators, approved by the commission, and binding on all participants.
A Worked Example: Tracing Power from Generator to Bill
Consider a household’s electricity traveling backward from the meter to its source, and watch the jurisdictional line move. The retail rate on the bill was set by the state utility commission in a rate case that determined the utility’s distribution costs and allowed return. Embedded in that retail rate is the wholesale power cost, which the state commission accepted as filed because the filed rate doctrine required it to honor the commission approved wholesale tariff. That wholesale cost was set in the organized market’s day ahead auction, where generators offered supply and the regional operator dispatched the cheapest feasible combination, producing a locational marginal price under market rules the commission approved in tariff filings. The generator reached the market over transmission service taken under the open access tariff that Order 888 required and the regional operator administers under the Order 2000 framework. The transmission lines that will carry tomorrow’s power were planned in the regional process Order 1000 required, with costs allocated under the beneficiary pays principle the commission approved. And the grid over which it all flows must meet the reliability standards the commission approved under section 215.
Every layer of that chain is an instrument this article has described: the state retail rate case, the filed wholesale tariff, the auction under approved market rules, the open access tariff, the regional plan, the reliability standard. The jurisdictional line runs through the chain at exactly one point, between the wholesale cost the commission governs and the retail rate the state sets, and the filed rate doctrine is the stitching that holds the two sides together. A reader who can trace that chain has the practitioner’s mental model of the American electricity system, and can locate any policy dispute, a state generation subsidy, a transmission cost fight, a demand response rule, on the correct side of the line.
The same tracing exercise works for natural gas. The wellhead production the commission does not regulate flows into gathering lines the commission does not regulate, then into the interstate pipeline whose transportation rate the commission approved in a section 4 rate case and whose construction the commission authorized by certificate, then into the local distribution company’s city gate purchase at a wholesale price under a commission jurisdictional tariff, and finally to the household at the retail rate the state commission set. The certificate, the tariff, and the filed rate doctrine do the same work in gas that their counterparts do in electricity: they mark the federal segments of a continuous physical journey from production to burner tip. The commission’s jurisdiction is thus not a territory but a set of segments, and the art of energy practice is knowing which segment a dispute occupies.
The Action Congress Authorized That Never Came
The template for this framework asks what the statute authorized that never happened, and the commission’s history supplies a clean example. The Energy Policy Act of 2005 added section 216 to the Federal Power Act, giving the commission a backstop siting authority for electric transmission in designated national interest corridors. The design was that the Department of Energy would designate corridors where transmission congestion harmed consumers, and if a state withheld approval of a project in a corridor for more than a year, the commission could step in and authorize the project. In practice the backstop never functioned as designed. Corridor designations drew litigation, the courts narrowed the trigger for federal intervention, and states and project developers largely continued to work through state siting processes. The commission’s siting power thus remains, with the corridor exception that never matured, a gas pipeline power rather than an electric transmission power. The contrast with the certificate authority under the Natural Gas Act is instructive: where Congress gave the commission a direct and unconditional siting tool, the commission built the interstate pipeline network; where Congress gave it a conditional backstop layered over state authority, the tool sat largely unused.
The episode also illustrates the limits of the orders not statutes claim. The commission can stretch the just and reasonable standard to design markets, but it cannot stretch a siting backstop that Congress wrote with conditions into an unconditional siting power. The commission’s creativity operates within the grants Congress made, and section 216 shows what happens when the grant is hedged. The gap between text and policy has a boundary, and the boundary is the text.
The mechanics of the failure are worth understanding because they show how conditional grants die. The statute required the Department of Energy to designate corridors, the commission to find that a state had withheld approval for more than a year, and the courts to sustain each step. Corridor designations drew challenges from states that objected to the federal intrusion into siting, and the courts read the one year withholding trigger narrowly, holding that a state’s timely denial within the year did not count as withholding. Each narrowing reduced the set of projects eligible for the backstop, and developers, facing the uncertainty, chose to work through state processes rather than gamble on federal preemption. The lesson for the practitioner is that a conditional federal power is only as strong as its weakest condition, and Congress wrote section 216 with several. The commission learned to achieve transmission expansion through the Order 1000 planning process instead, which works with state authority rather than overriding it, and which has proven the more durable instrument precisely because it does not depend on the backstop.
What the Commission Does Not Do
An article about the least understood major regulator should also clear away the most common misunderstandings, because the commission’s power is easier to grasp once its limits are stated. The commission does not set the electricity rates paid by households and businesses. Those retail rates are set by state utility commissions in traditionally regulated states and by retail suppliers in restructured states, building on the wholesale costs the commission oversees. A consumer who writes to the commission about a high electric bill will be directed to the state commission, because the retail bill is outside federal jurisdiction.
The commission does not decide where power plants are built. Generation siting is a state function, exercised through state certificates, permits, and in some states integrated resource planning. The commission’s only transmission siting backstop, for designated national interest corridors, is a narrow exception that proves the rule. A state that does not want a power plant does not need the commission’s permission to refuse it, and a developer who wants to build one needs the state’s permission regardless of what the commission thinks.
The commission does not write environmental standards. Its environmental role is procedural and project specific: the NEPA review attached to pipeline certificates and hydroelectric licenses. It does not set emissions limits, water quality standards, or endangered species protections. Those belong to the Environmental Protection Agency, the states, and the Fish and Wildlife Service. When the commission’s certificate docket discusses environmental impacts, it is applying NEPA’s procedural requirements to its own licensing decision, not exercising substantive environmental regulatory authority.
The commission does not certificate oil pipelines. Its oil jurisdiction covers rates and practices under the frozen 1977 statute, not construction authorization. An oil pipeline company does not need a commission certificate to build; it needs to charge just and reasonable rates once it operates. This asymmetry between gas and oil, certificate plus rates for gas, rates only for oil, is a historical accident of the different statutes, but it is the law, and it explains why oil pipeline controversies look different from gas pipeline controversies.
Finally, the commission does not guarantee outcomes. It approves market rules designed to produce just and reasonable prices, but it does not promise that any particular auction will clear at any particular level. It approves reliability standards designed to keep the lights on, but it does not promise that no blackout will occur. It certificates pipelines found to serve the public convenience and necessity, but it does not promise that the need will materialize as projected. The commission deals in frameworks, standards, and procedures. The results emerge from the frameworks, and judging the commission means judging the frameworks, which is the work this article has tried to make possible.
Transparency as an Instrument: OASIS, Reporting, and Conduct
Order 889’s information infrastructure deserves treatment as an instrument in its own right, because transparency is how the commission polices discrimination between rate cases. The Open Access Same Time Information System requires transmission providers to post available transfer capability, service requests, and curtailments on a common electronic platform, so that every market participant sees the same grid conditions at the same time. The standards of conduct then police the use of that information inside the transmission owner: employees engaged in transmission operations may not share nonpublic information with employees engaged in wholesale marketing, and the commission audits compliance with the separation. The design reflects a regulatory insight. Discrimination in a network industry is often informational before it is economic; the competitor who learns of congestion an hour late has already lost the trade. By standardizing the information flow, the commission made discrimination visible and therefore deterrable.
The reporting obligations extend beyond transmission. Sellers authorized to charge market based rates file regular reports on their transactions, which feed the commission’s market surveillance. The commission’s market monitoring functions, housed in the regional operators and overseen by the commission, watch the auctions for anomalous bidding and refer suspected manipulation for investigation. None of these instruments sets a price. All of them make the price formation process legible to the regulator, which is the precondition for the architectural authority the commission exercises. A market the commission cannot see is a market it cannot keep just and reasonable, so transparency is not an accessory to the market design. It is part of the design.
The standards of conduct deserve a final note because they show how the commission polices the boundary it created. Functional unbundling separated the transmission owner’s wires business from its marketing business, but separation on paper means little without rules against the informal flows of information and influence that shared ownership invites. The standards prohibit transmission function employees from sharing nonpublic transmission information with marketing function employees, require the posting of any discretionary waivers, and subject the separation to compliance audits. Violations draw enforcement attention not because any particular trade was harmed but because the informational playing field the open access regime depends on was tilted. The commission thus treats the integrity of the information environment as a regulatory good in its own right, which is consistent with the whole architecture: the commission governs the conditions of competition rather than its outcomes.
Certificates and the Other Authorizations
The commission’s certificate is the central federal authorization for an interstate pipeline, but it is not the only authorization the project needs. The Energy Policy Act’s lead agency designation makes the commission the coordinator of all federal authorizations, which means the commission’s NEPA review serves the permitting needs of the cooperating federal agencies rather than each agency running its own environmental process. State authorizations run on a parallel track: water quality certifications, coastal zone consistency determinations, and state air permits, each under its own statute and each litigable in its own forum. The certificate order typically identifies the additional authorizations required and conditions construction on obtaining them, which means the commission’s yes is necessary but not always sufficient.
That multiplicity of authorizations is why certificate litigation has so many fronts. A challenger who loses the need determination at the commission can challenge the environmental review in the court of appeals, challenge a state water certification in state court, and challenge the eminent domain compensation in the condemnation proceeding. Each forum applies its own standard, and the project must survive all of them. The commission’s defenders argue that this gauntlet already subjects pipelines to searching review; project opponents argue that the fragmentation lets the commission approve projects whose full impacts no single forum confronts. The article reports the structure without resolving the debate, because the structure is what the statutes built and the debate is what the politics supplies.
The Natural Gas Rate Case
The Natural Gas Act’s rate machinery parallels the Federal Power Act’s, with its own procedural texture. Sections 4 and 5 of the act, 15 U.S.C. 717c and 717d, require just and reasonable rates for jurisdictional transportation and sales and authorize the commission to determine the lawfulness of rates. Under section 4 a pipeline files a proposed rate change, and the commission may suspend the new rate and allow it to take effect subject to refund while the commission investigates, which protects shippers during the review period. Under section 5 the commission investigates existing rates on its own motion or on complaint and prescribes the lawful rate going forward. The two sections mirror the Federal Power Act’s 205 and 206 division between proposed and existing rates, and the same burden logic applies: the pipeline supports its filing under section 4, while a challenger to an existing rate faces the heavier lift of showing the current rate unlawful under section 5.
Pipeline rate cases turn on cost allocation as much as on total cost. A pipeline’s system serves shippers with different contract types, different receipt and delivery points, and different service priorities, and the rate design must allocate the pipeline’s fixed costs among them without undue discrimination. The commission’s rate design policies, developed through decades of adjudicated cases, supply the templates: how capacity costs are assigned between reservation and usage charges, how fuel and lost gas are accounted for, how new facilities are rolled into existing rates. Each rate case applies those templates to the pipeline’s particular system, which is why gas rate litigation is fact intensive even though the legal standard is a single sentence. The certificate and the rate case are thus the two halves of pipeline regulation. The certificate decides whether the pipe gets built; the rate case decides what shippers pay to use it.
Complaints, Investigations, and the Section 206 Docket
Section 206 is the commission’s roving authority to correct what the market or the tariffs get wrong. The section provides that when the commission finds any rate, charge, classification, rule, regulation, practice, or contract affecting a jurisdictional rate to be unjust, unreasonable, unduly discriminatory, or preferential, the commission shall determine the just and reasonable substitute to be observed going forward. The trigger can be a complaint filed by a market participant, a state commission, or a customer group, or the commission’s own investigation. The complaint docket is where the industry litigates the meaning of the market rules in real time: a generator challenging a market operator’s dispatch decision, a marketer challenging a tariff interpretation, a state challenging a cost allocation.
The investigation half of section 206 is what produced the market making orders. In each case the commission identified an existing practice, the closed transmission system, the absence of regional planning, the exclusion of demand response from comparable compensation, found it unjust or unduly discriminatory, and prescribed the replacement practice. That is why the orders read as findings first and designs second: the statute requires the finding as the predicate for the prescription. A practitioner challenging a commission rule therefore attacks the finding, arguing the existing practice was not discriminatory or the record does not support the determination, because without the finding the prescription has no statutory footing. The courts review that attack deferentially but genuinely, which is why the commission builds the thousand page records that make its major rules litigation proof.
How to Read a Commission Order
Commission orders follow a predictable architecture, and learning it accelerates every other part of energy practice. The order opens with the procedural background: what was filed, who intervened, what the commission is deciding. The background section narrates the relevant history, often at length, because the commission writes for a reviewing court as well as for the parties. The discussion section then works through the issues one by one, stating the commission’s determination and the reasoning supporting it, with citations to the record and to precedent. The ordering paragraphs at the end state the legal directives in numbered commands: the tariff is accepted, the compliance filing is due in sixty days, the rehearing period runs from the order’s date. Concurrences and dissents follow, and the skilled reader studies them because they reveal the fault lines the next rulemaking will exploit.
Three reading habits distinguish the experienced practitioner. First, always identify the statutory hook in the discussion section, the specific sentence of section 205, 206, 7, or 215 on which the determination rests, because the hook defines the scope of what the commission can and cannot do on rehearing and appeal. Second, read the ordering paragraphs as the operative law and the discussion as the reasoning that defends them; parties comply with the paragraphs and litigate the reasoning. Third, track the compliance filings the order requires, because the commission often issues the headline rule in the order and works out its details in the compliance proceedings that follow. Order 1000’s regional compliance filings, in which each region proposed its planning process and cost allocation method for commission approval, are the paradigmatic example: the rule announced the principles and the compliance docket built the regional variations.
Rehearing orders deserve their own reading habit. When parties seek rehearing of a major rule, the commission’s rehearing order typically grants rehearing in part, clarifies ambiguous provisions, and denies the rest, which means the final legal meaning of the rule emerges across two documents rather than one. The courts review the rule as modified on rehearing, so a practitioner who reads only the original order misses the refinements that determine how the rule actually operates. Delegated orders, issued by staff under authority the commission has delegated, handle the routine tariff filings and minor matters, and they become final unless a party seeks commission review. The docket is thus layered: delegated staff orders for the routine, commission orders for the contested, rehearing orders for the refined, and appellate decisions for the disputed. Knowing which layer a question occupies tells the practitioner how much precedential weight the answer carries.
Why the Line Holds: The Institutional Logic
The jurisdictional line has held for eighty years not because it is conceptually clean but because the institutions on each side need it. The commission needs the line to keep its docket within manageable bounds; a commission responsible for retail rates in fifty states would drown in rate cases and lose the technical focus that makes its market designs work. The states need the line to preserve their authority over the retail relationship, the siting decisions, and the distribution systems their voters experience directly. The courts need the line because it gives them a administrable test, the directly affects inquiry and the preemption holdings, rather than an open ended inquiry into the wisdom of energy policy. Each institution thus has a stake in maintaining the boundary, which is why the line survives even though the physics of the grid ignores it.
The line also holds because the instruments are designed to manage the boundary rather than to erase it. The filed rate doctrine lets the federal rate flow into the state rate case without either regulator surrendering authority. The Hughes limitation lets states pursue generation policy through untethered measures while keeping the wholesale price federal. The Order 1000 planning process lets state public policies drive regional transmission planning while keeping cost allocation under commission approved methods. In each case the mechanism converts a potential jurisdictional collision into a division of labor. The commission’s genius, if the word is permitted in an analytical article, is not in winning turf battles but in designing instruments that make the turf battles unnecessary. The open access tariff ended the fight over transmission discrimination by making the terms of access uniform. The regional organization ended the fight over balkanized operations by putting a single operator in charge. The planning process ended the fight over who builds transmission by giving every stakeholder a seat at the planning table and a commission approved method for allocating the costs. The reliability regime ended the fight over voluntary versus mandatory standards by making the standards law. In each case the commission replaced a contest over authority with a procedure for exercising it, and the procedure, once embedded in tariffs and standards, outlasted the controversy that produced it.
The Capacity Market as Jurisdictional Flashpoint
The capacity auction deserves separate treatment because it has generated the sharpest jurisdictional fights of the market era. Unlike the energy auction, which pays generators for electricity actually produced, the capacity auction pays resources for the commitment to be available when needed, which makes it a forward market for reliability. The commission’s theory is that capacity payments directly affect the wholesale rate for electricity because they compensate the fixed costs of the generation fleet that serves load. States see the same auction differently: as a mechanism that determines which power plants get built and survive, which is the resource planning function the states consider their own. Hughes arose from exactly that collision, when Maryland tried to secure new generation by guaranteeing a price conditioned on clearing the federally regulated capacity auction.
The commission’s response to state capacity initiatives has been to defend the auction’s integrity through its tariff authority rather than to forbid state policy. When a state program threatens to distort the auction’s price signal, by injecting subsidized capacity that suppresses the clearing price for everyone, the commission’s remedy is to adjust the auction rules, through the minimum offer price provisions and related buyer side mitigation, so that the auction continues to produce a just and reasonable price despite the state intervention. The state keeps its program; the auction keeps its price formation. That accommodation is the Hughes limitation in operational form: the state may pursue its generation preferences through untethered measures, and the commission may protect its wholesale market from the effects of those measures through market rule changes. The two sovereigns thus regulate the same electrons from opposite sides, and the tariff is the instrument that keeps their actions from canceling each other.
The Commission in the Statutory Sequence
The commission’s authorities arrived in four legislative waves, and the sequence explains why the portfolio looks the way it does. The first wave was the New Deal: the Federal Power Act of 1935, Title II of the Public Utility Act, gave the Federal Power Commission jurisdiction over interstate wholesale electricity, and the Natural Gas Act of 1938 extended the model to gas. Both statutes used the just and reasonable standard borrowed from railroad regulation, and both drew the wholesale retail line that still organizes the field. The second wave was the 1970s reorganization: the Department of Energy Organization Act of 1977 created the commission as an independent body within the new department, consolidating the Federal Power Commission’s functions with the oil pipeline authority transferred from the Interstate Commerce Commission. The Public Utility Regulatory Policies Act of 1978, treated in its own article, cracked open the generation monopoly by creating qualifying facilities and obliging utilities to buy their power, which supplied the independent generators the commission’s later market orders would enfranchise.
The third wave was the market era, and it came by order rather than by statute. Congress did not legislate open access or regional markets; the commission ordered them under the 1935 standard, as this article has shown. The fourth wave was the Energy Policy Act of 2005, which ratified the commission’s expanded role after the fact: it added the reliability title, expanded enforcement authority, designated the commission as lead agency for pipeline environmental review, and supplied the transmission corridor backstop that never matured. The pattern across the four waves is consistent. Congress writes the jurisdictional grants and the standards in moments of legislative energy, the commission builds the operating system in the decades between, and Congress returns periodically to codify, correct, or expand what the commission has built. The survey of energy legislation since 1950 places these waves in their full chronological context.
That sequence is also the reason the commission’s law is order heavy and statute light. The statutes set the frame at long intervals; the orders fill the frame continuously. A practitioner who reads only the statutes knows the boundaries of the commission’s power but none of its content. A practitioner who reads only the orders knows the content but risks missing the jurisdictional limits that the next court case will enforce. The article’s method, statute outward to the orders and back to the courts, is the reading method the field requires.
Putting the Table to Work: Five Client Questions
The jurisdiction and instrument table below is not a decoration. It is a diagnostic tool, and the way to learn it is to run client questions through it the way a practitioner does. Each question below names the mechanism, the instrument, and the forum, showing how the five mechanisms combine in real practice.
A generator owner asks why a transmission provider is curtailing its deliveries while the provider’s own generation flows freely. The table points to the first two rows: interstate transmission is commission jurisdiction under sections 201, 205, and 206, and the instrument is the open access transmission tariff. The practitioner pulls the provider’s tariff, compares the curtailment provisions with the service the provider gives itself, and asks whether the difference is an undue preference under section 205(b). If it is, the remedy is a complaint under section 206 asking the commission to find the practice unjust or unduly discriminatory and to order comparable service. The forum is the commission in the first instance and the courts of appeals on review. The order sequence matters here too: Order No. 888 created the comparability obligation, and Order No. 889’s information system supplies the evidence of what capacity was actually available when the curtailment occurred.
A landowner asks what to do about a pipeline survey crew on her property and a letter offering an easement. The table points to the certificate rows. Interstate pipeline construction requires a section 7 certificate, and the certificate carries eminent domain under section 7(h). The practitioner checks whether a certificate has issued: if the project is still in the application stage, the landowner can intervene in the docket, challenge the need showing, and contest the route in the environmental review. If the certificate has issued, the eminent domain power has attached, and the fight moves to the condemnation proceeding over compensation and to the courts of appeals over the certificate’s validity. The environmental review row matters as well, because the commission’s NEPA document is the record on which route alternatives and mitigation were considered. The landowner’s strongest arguments are usually about the specific parcel: the availability of a less damaging route, the adequacy of the construction mitigation, and the compensation for the taking.
A state energy office asks how to design a generation incentive that survives judicial review. The table’s wholesale rows give the warning and the Hughes limitation gives the path. Any payment conditioned on clearing the commission jurisdictional auction is preempted, because it functionally sets the wholesale rate. The practitioner therefore designs the incentive untethered from wholesale market participation: a tax credit per megawatt of installed capacity, a grant for construction costs, a state owned facility, or a contract whose payments do not vary with the auction clearing price. The state keeps its full authority over siting and over incentives of this kind, and the commission has no basis to object, because the program never touches the wholesale transaction. The design exercise is an application of the jurisdictional line to a drafting problem, and getting it right requires understanding exactly where the line sits.
A utility asks who will pay for a proposed regional transmission line. The table points to the planning and cost allocation row: commission jurisdiction under sections 205 and 206 as interpreted in Order No. 1000, with the instrument being the regional planning process and the benefit based allocation in the tariff. The practitioner enters the planning process early, because the needs identification stage determines which projects are evaluated, and intervenes in the cost allocation proceeding with evidence about where the benefits actually fall. The arguments are quantitative: power flow studies showing congestion relief, reliability analyses showing avoided outages, and economic models showing production cost savings. The commission’s standard is rough commensurability between costs and benefits, which leaves room for advocacy about how benefits are measured. The states whose customers face the largest shares will argue for narrower benefit definitions, and the project’s supporters will argue for broader ones. The outcome is a tariff provision, reviewable in the courts of appeals, that determines the regional distribution of a large investment’s cost.
A utility compliance officer asks how to prepare for a reliability audit. The table points to the reliability row: the commission approves the standards and enforces them, with the Electric Reliability Organization developing them. The practitioner inventories which approved standards apply to the company’s registered functions, reviews the company’s compliance evidence for each requirement, and identifies gaps before the auditors do. The key insight is that the standards are law, not guidance, and that the audit tests evidence of compliance rather than general good practice. A company with excellent operations but poor documentation fails an audit that a well documented company passes. When a violation is found, the enforcement proceeding calibrates the penalty to the risk the violation created, and the company’s compliance history and cooperation affect the outcome. The reliability mechanism rewards the same discipline the other mechanisms reward: know the instrument, build the record, and meet the standard on the evidence.
These five questions show the table working as a map of the whole field. The jurisdictional rows answer who decides. The instrument column answers how the decision is made. The review route answers where to challenge it. A practitioner who can run any new question through these three columns has the working knowledge this article aims to teach, and the One Test sentence from the introduction is simply the compressed version of the same skill.
The Commission’s Vocabulary: Terms of Art
Every specialized field speaks in terms of art, and the commission’s vocabulary repays study because each term names an instrument of power. A tariff is not a tax but a filed schedule of rates, charges, and the rules affecting them, carrying the force of law once approved. To say that market rules live in the tariff is to say that they are enforceable against all participants and changeable only through commission process. The open access transmission tariff is the specific pro forma document Order No. 888 required, the template that made comparability a legal obligation rather than a business courtesy.
A certificate of public convenience and necessity is the federal license for an interstate gas pipeline, and its name preserves the Progressive Era conception of regulated entry: the applicant must show that the public needs the service before being allowed to provide it. The phrase sounds quaint, but the showing is rigorous, and the eminent domain that follows the certificate gives the quaint phrase modern force. Just and reasonable is the standard against which every rate and practice is measured, inherited from railroad regulation and applied across three eras of ratemaking without changing its words. Undue discrimination is its companion prohibition, the rule that the same terms must be offered to all similarly situated customers, which the commission used to attack transmission favoritism in the 1990s just as the Interstate Commerce Commission used it against railroad favoritism in the 1900s.
A regional transmission organization is an independent operator of transmission facilities and wholesale markets over a multi state region, encouraged into existence by Order No. 2000 and governed by a commission approved tariff. Independence is the defining characteristic: the RTO has no financial interest in the generation it dispatches, which is what makes its administration of open access credible. The locational marginal price is the price of the next increment of electricity at a specific location on the grid, reflecting generation cost plus the effects of transmission congestion, and it is the price signal around which the organized markets are built. Demand response is the reduction of consumption in response to market signals, treated by Order No. 745 as functionally equivalent to generation for compensation purposes.
The filed rate doctrine is the rule that a commission jurisdictional rate must be given effect in state proceedings, the legal mechanism that makes the jurisdictional line stick. Cost allocation is the determination of who pays for shared facilities, governed since Order No. 1000 by the principle that costs follow benefits. The Electric Reliability Organization is the body the commission certifies to develop mandatory reliability standards, a role filled by the North American Electric Reliability Corporation since July 2006. Each term compresses a history: the tariff compresses the 1935 Act’s filing requirement, the certificate compresses the 1938 Act’s entry control, the RTO compresses Order No. 2000’s market vision, and the reliability organization compresses the 2005 Act’s response to voluntary standards’ failure. To speak the vocabulary fluently is to carry the history in the words, which is why practitioners learn the terms before they learn the arguments. The commission rewards precision in language because its orders turn on the exact meaning of these phrases, and a filing that misuses them signals unfamiliarity with the forum. Master the terms, and the mechanisms they name become navigable.
Closing Assessment
The Federal Energy Regulatory Commission is the least understood major regulator in the federal government, and the misunderstanding is structural. Its name suggests a narrow technical body. Its actual function is the design and supervision of the markets that deliver electricity and gas to the American economy, plus the siting of interstate gas pipelines and the enforcement of bulk power reliability. It does that work with five instruments: the jurisdictional line that allocates power between the commission and the states, the just and reasonable standard that authorizes its market designs, the sequence of orders that built open access and regional markets, the certificate that sites pipelines and carries eminent domain, and the reliability standards that converted industry practice into law. The Supreme Court has drawn the jurisdictional line around the directly affects test and the preemption of state wholesale rate setting. The commission has filled the space inside that line with tariffs, auctions, and standards.
The series thesis finds its widest expression here. The distance between the 1935 statutory phrase and the 2016 electricity market is the distance between a sentence about reasonable rates and a continental system of auctions, regional operators, and planning processes that no legislator in 1935 imagined. That distance was crossed by agency orders, sustained by courts, and bounded by the jurisdictional line. Whether the crossing was wise is a separate question from whether it was lawful, and the article has tried to equip the reader to ask both.
The five instruments repay a final review in the order a practitioner encounters them. The jurisdictional line tells the practitioner which regulator decides. The just and reasonable standard tells the practitioner what legal test the decision must satisfy. The order sequence tells the practitioner how the current market design came to be and which tariff provisions embody it. The certificate tells the practitioner how pipelines get built and why landowners fight them. The reliability standards tell the practitioner where engineering practice becomes enforceable law. The review routes in the jurisdiction and instrument table tell the practitioner where each decision can be challenged. That is the complete toolkit, and it fits on one table because the commission’s authority, for all its economic consequence, is organized around a small number of statutory sentences applied through a disciplined set of instruments. The reader who can state the jurisdictional line, name the orders, explain the certificate and its eminent domain consequence, and describe the reliability regime has passed the One Test, and understands the regulator that the statutes built and the orders made.
Frequently Asked Questions
Q: What does FERC regulate?
The Federal Energy Regulatory Commission regulates the transmission of electric energy in interstate commerce and the sale of electric energy at wholesale in interstate commerce under the Federal Power Act, the transportation of natural gas in interstate commerce and wholesale gas sales under the Natural Gas Act, oil pipeline rates under the Interstate Commerce Act as frozen on October 1, 1977, and the reliability of the bulk power system under section 215 of the Federal Power Act. It issues certificates of public convenience and necessity for interstate gas pipelines, approves tariffs and market rules, and enforces mandatory reliability standards. It does not regulate retail electricity or gas sales, local distribution, gas production or gathering, or the siting of power plants; those belong to the states.
Q: What is the difference between FERC and state utility regulators?
The commission operates at the wholesale and interstate layer while state utility commissions operate at the retail and local layer. The commission approves the tariffs, market rules, and wholesale rates for interstate electricity transmission and sales and for interstate gas transportation and sales. State commissions set the retail rates households and businesses pay, regulate local distribution wires and pipes, and site most power plants. The two layers connect through the filed rate doctrine: the state must honor the wholesale rate the commission has approved when it sets retail rates. Disputes about where one layer ends and the other begins are resolved by the courts, most importantly through the Supreme Court’s directly affects test and its preemption decisions.
Q: Does FERC approve gas pipelines?
Yes. Under section 7(c) of the Natural Gas Act, no natural gas company may construct or operate jurisdictional interstate pipeline facilities without a certificate of public convenience and necessity issued by the commission. The applicant files a detailed application, interested parties intervene, commission staff conducts environmental review under the National Environmental Policy Act, and the commission issues an order granting or denying the certificate based on whether the project is required by the present or future public convenience and necessity. The certificate typically carries conditions, including environmental mitigation measures. Denied or conditioned applicants, intervenors, and landowners may seek rehearing and then judicial review in the federal courts of appeals under section 19 of the Natural Gas Act.
Q: Can a FERC certificate give a company eminent domain?
Yes. Section 7(h) of the Natural Gas Act, added in 1947, provides that a certificate holder unable to acquire necessary rights of way by contract may exercise the right of eminent domain in the federal district court where the property is located or in the state courts. The eminent domain power belongs to the certificate holder, not to the commission; the commission decides whether the project serves the public convenience and necessity, and the company then negotiates with landowners and files condemnation actions only where negotiation fails. Compensation is set in the condemnation proceeding, not by the commission. This is the commission’s most politically contested function because it makes a federal certificate the legal foundation for condemning private land for a private company’s project.
Q: What was FERC Order 888?
Order No. 888, issued April 24, 1996, required every transmission owner to offer open access transmission service on the same terms it gave its own generation, ending the practice by which vertically integrated utilities favored their own power plants on their own wires. The order imposed functional unbundling and required each jurisdictional transmission provider to file a pro forma open access transmission tariff standardizing service terms. Order No. 889, issued the same day, created the Open Access Same Time Information System for posting available capacity and imposed standards of conduct separating transmission and marketing personnel. Together the orders converted the transmission grid into a common carrier system and laid the foundation for every competitive electricity market that followed.
Q: How does FERC set just and reasonable rates?
The commission rarely sets a numerical price. Instead it approves the tariffs, market rules, and rate methodologies under which prices are determined, and it orders changes to those instruments when it finds existing rates or practices unjust, unreasonable, or unduly discriminatory under sections 205 and 206 of the Federal Power Act. In the monopoly era the method was cost of service ratemaking, allowing recovery of prudent costs plus a fair return. In the market era the commission approves market based rate authority for sellers that lack market power and approves the auction rules of the organized markets, treating prices produced by approved competitive processes as just and reasonable. The section 205(c) filing requirement makes the approved tariff the legal rate, so the commission governs prices by governing the rules that produce them.
Q: Who appoints FERC commissioners?
The President nominates the five commissioners and the Senate confirms them, under section 401(b) of the Department of Energy Organization Act. No more than three commissioners may belong to the same political party. They serve staggered five year terms, and the President designates one member as chairman, the commission’s executive and administrative head. A commissioner may be removed only for inefficiency, neglect of duty, or malfeasance in office. The party balance rule and the staggered terms are the classic protections of an independent agency: they prevent any single President from instantly remaking the commission and let energy market policy move more slowly than the electoral cycle, negotiated through orders that outlast individual administrations.
Q: Can states be preempted by FERC wholesale rules?
Yes. The Supreme Court has held repeatedly that the Federal Power Act preempts state action that invades the commission’s exclusive wholesale domain. In Nantahala Power and Light v. Thornburg, 476 U.S. 953 (1986), the Court held that commission approved wholesale rates preempt inconsistent state retail ratemaking, so a state may not declare a federal wholesale rate unreasonable in a retail rate case. In Mississippi Power and Light v. Mississippi, 487 U.S. 354 (1988), the Court held that state prudence reviews of commission mandated wholesale cost allocations are preempted. In Hughes v. Talen Energy Marketing, 577 U.S. 364 (2016), the Court unanimously struck down Maryland’s contract for differences program because it functionally set an interstate wholesale rate. States keep measures untethered to wholesale market participation, such as tax incentives and direct subsidies.
Q: What role does the Federal Power Act give the commission?
The Federal Power Act gives the commission jurisdiction over the transmission of electric energy in interstate commerce and the sale of electric energy at wholesale in interstate commerce, under section 201, and it supplies the just and reasonable and not unduly discriminatory standard in sections 205 and 206 that the commission has used to build the modern market architecture. The act expressly excludes from commission jurisdiction facilities used in local distribution and facilities used for generation, which reserves retail sales, distribution, and plant siting to the states. The 2005 amendments added section 215 on reliability and section 216 on transmission corridors. The act is thus both the commission’s charter and its boundary: everything the commission has built in electricity rests on its text, and everything beyond its text belongs to the states.
Q: What was Order 745 and how did it treat demand response?
Order No. 745, issued March 15, 2011, required the organized wholesale markets to pay demand response resources the full locational marginal price when dispatching demand response is cost effective under the rule’s net benefits test. The commission’s theory was comparability: a megawatt of reduced demand performs the same grid function as a megawatt of generated supply, so paying them differently discriminates against the demand side. The order provoked the jurisdictional challenge decided in FERC v. Electric Power Supply Association, 577 U.S. 260 (2016), where the Supreme Court upheld the rule six to two, holding that wholesale market compensation of demand response directly affects wholesale rates and that the rule did not regulate retail sales because states could prohibit their retail consumers from participating.
Q: What does Order 1000 require for transmission planning and cost allocation?
Order No. 1000, issued July 21, 2011, required transmission providers to participate in regional planning processes that consider transmission needs driven by public policy requirements, to coordinate planning with neighboring regions, and to adopt commission approved methods for allocating the costs of new facilities. Its cost allocation principle was beneficiary pays: costs should be allocated roughly commensurate with benefits. The order also removed the federal right of first refusal from jurisdictional tariffs, opening regional transmission construction to competitive bidding by non incumbent developers. Order 1000 addressed the long term problem the earlier market orders left unsolved, who plans the future grid and who pays for it, by adding a regional planning layer alongside the operational layer of the regional transmission organizations.
Q: How does the commission enforce electric reliability standards?
The commission enforces reliability standards that it has approved but does not write itself. Under section 215 of the Federal Power Act, added by the Energy Policy Act of 2005, the certified Electric Reliability Organization develops proposed standards through an open industry process, and the commission approves, remands, or directs modification of each proposal. A standard becomes enforceable only upon commission approval; the commission approved 83 of the first 107 proposed standards in Order No. 693 in 2007. Violations of approved standards carry both monetary and nonmonetary penalties, which converted what had been voluntary industry practice into federal law. Enforcement proceedings run through the commission with judicial review available, and the commission’s oversight role is to judge the standards, approve them, and make noncompliance costly.
Q: How does a natural gas company obtain a certificate of public convenience and necessity?
The company files an application under section 7(c) of the Natural Gas Act describing the proposed pipeline, its route, its capacity, and the markets it would serve. The commission opens a docket and interested parties, including landowners, competing pipelines, customer groups, states, and environmental organizations, intervene. Commission staff conducts environmental review under the National Environmental Policy Act, typically an environmental assessment or, for major projects, a full environmental impact statement, with the commission acting as lead agency. The commission then issues an order applying the section 7(e) standard: whether the applicant is able and willing to perform and whether the project is required by the present or future public convenience and necessity. Granted certificates carry conditions, and parties may seek rehearing and appellate review.
Q: Does the commission set the price a household pays for electricity?
No. The commission approves wholesale tariffs, market rules, and rate methodologies; the state utility commission sets the retail rate on the household bill. In the organized wholesale markets, prices are set by auction under commission approved rules: generators offer supply, the market operator dispatches the cheapest feasible combination, and the clearing price emerges from the bids. The commission regulates the auction’s structure, including bidding rules and market power mitigation, to keep the resulting price just and reasonable. Under the filed rate doctrine the state must honor the approved wholesale costs when it sets retail rates, so the household price reflects a state decision built on top of a federal market design, not a price fixed by the commission.
Q: How can a commission order or tariff be challenged in court?
A party aggrieved by a commission order must first seek rehearing before the commission; only after the commission rules on rehearing may the party petition the federal courts of appeals for review, under section 313 of the Federal Power Act or section 19 of the Natural Gas Act. Courts review market and rate orders deferentially, upholding them when the commission has offered a reasoned explanation grounded in the record, and they review the jurisdictional boundary de novo as a question of statutory interpretation, which is how the directly affects test and the preemption holdings emerged. Certificate challengers attack the adequacy of the commission’s record on need and environmental review. Condemnation actions under section 7(h) proceed separately in district or state court, where the issue is compensation rather than the certificate’s validity.
Q: How does the commission regulate oil pipelines?
The commission regulates oil pipeline rates and practices under the Interstate Commerce Act as it existed on October 1, 1977, not under the act as recodified in Title 49. The Hepburn Act of 1906 first brought oil pipelines under Interstate Commerce Commission regulation; the Department of Energy Organization Act transferred that authority to the commission effective October 1, 1977; and section 4(c) of Public Law 95-473 froze the applicable text at its 1977 content, printed as an appendix to Title 49 of the United States Code. The commission applies the frozen act’s just and reasonable and anti discrimination standards to oil pipeline tariffs, using ratemaking methods developed for that industry including indexed rate ceilings. The frozen statute fixes the substantive law at its 1977 content, making oil pipeline regulation the commission’s most historically layered function.
Q: What is the directly affects test from FERC v. Electric Power Supply Association?
The directly affects test is the Supreme Court’s boundary for the commission’s jurisdiction over practices affecting wholesale rates. Decided January 25, 2016 by 6 to 2, the case held that the Federal Power Act reaches rules that directly affect the wholesale rate, not merely rules with some downstream effect on it. Demand response compensation qualified because the payment formula necessarily lowers wholesale prices by displacing higher priced generation bids. The test matters because every energy rule affects both sides of the federal state line; the question is whether the rule operates directly on the wholesale transaction, which keeps the commission inside its statutory grant.
Q: Why did Hughes v. Talen Energy preempt Maryland’s generation contract?
Maryland guaranteed a new generator a fixed capacity price so long as it cleared the PJM capacity auction, topping up the difference when the auction price fell short and clawing back the surplus when it exceeded the guarantee. Decided April 19, 2016, the unanimous Court held the program preempted because it functionally set the price the generator received for a wholesale sale, disregarding the interstate wholesale rate the commission requires. The holding was limited: states may still encourage generation through tax incentives, land grants, direct subsidies, or state owned plants, so long as payment is not conditioned on clearing the commission jurisdictional auction.
Q: How do wholesale electricity auctions work under FERC approved tariffs?
In organized markets, generators offer supply and load serving entities bid demand into auctions run by regional operators under tariffs the commission has approved. In the capacity auction described in Hughes, the operator accepts the cheapest bids until projected demand is met, and every accepted seller receives the clearing price set by the highest accepted bid. The commission regulates the auction’s structure, bidding rules, demand curve, and market power mitigation to ensure a just and reasonable result, but the price itself is discovered by the bids. Energy markets work similarly on an hourly basis, with locational marginal prices reflecting congestion and losses at each node.
Q: How does environmental review attach to FERC pipeline certificates?
A pipeline certificate is a major federal action, so the National Environmental Policy Act requires the commission to examine its environmental impacts before deciding. The commission typically prepares an environmental assessment and a full environmental impact statement for major projects, analyzing route alternatives, construction impacts, and mitigation. The Energy Policy Act of 2005 designated the commission as lead federal agency coordinating all federal authorizations, so its review anchors related permits from the Army Corps of Engineers, the Fish and Wildlife Service, and state water quality certifications. Courts review the analysis for a hard look at consequences rather than reweighing the commission’s underlying judgment about project need.