Market-Based Rate Authority: FERC Application and Reporting

Market-based rate authority is the Federal Energy Regulatory Commission authorization that lets a wholesale electricity seller charge prices set by supply and demand instead of filing cost-based rate schedules that justify every dollar of infrastructure spending. FERC grants it to sellers who show that they and their affiliates lack horizontal and vertical market power, or have adequately mitigated it.¹ The framework sits primarily in 18 CFR Part 35, Subpart H, and covers wholesale sales of electric energy, capacity, and ancillary services. Without this authority, any entity making wholesale sales must operate under traditional cost-based rates or risk violating its tariff obligations.

Who Needs It

Any entity that sells electricity at wholesale — that is, for resale — within FERC’s jurisdiction needs either market-based rate authority or a cost-based rate tariff on file. That covers independent power producers with generation but no captive retail customers, power marketers that buy and sell without owning generation, and traditional utilities selling outside their franchised service territories. Even a utility that only occasionally pushes surplus power into the wholesale market after meeting its retail load needs MBR authority for those transactions.²

FERC’s jurisdiction stops at the wholesale line. Purely retail sellers are not subject to this requirement. If you sell any power at wholesale, though, you need appropriate rate authority for those sales regardless of volume.

What You Have to Prove

The core of any MBR application is the market power analysis required under 18 CFR 35.37. FERC wants to see that the applicant cannot manipulate prices or exclude competitors, and it evaluates that question along two axes.³

Horizontal Market Power

Horizontal market power measures whether a seller controls enough generation in a region to move prices. FERC applies two indicative screens, and passing both creates a rebuttable presumption that the seller lacks horizontal market power:⁴

The pivotal supplier analysis asks whether the region can meet its annual peak demand without the applicant’s capacity. If the market needs the applicant’s generation to keep the lights on at peak, the applicant has too much leverage.
The market share analysis, applied seasonally across four seasons, measures the applicant’s uncommitted capacity as a share of total uncommitted capacity in the relevant market. A dominant share in any season is a red flag.

Both screens count the applicant and its affiliates together, so corporate restructuring alone doesn’t shrink a seller’s footprint. The screens extend beyond basic energy sales to capacity, energy imbalance service, generation imbalance service, and primary frequency response service.³

Vertical Market Power

Vertical market power asks whether a seller can use control of transmission or inputs — natural gas pipelines, gas storage, coal supply — to block competitors from reaching the market. A seller that owns or controls transmission facilities, or whose affiliates do, must have an Open Access Transmission Tariff on file with FERC, or qualify for a waiver of that requirement.² The OATT is the mechanism that keeps competitors on nondiscriminatory footing.

Beyond transmission, applicants must describe any ownership or control of intrastate natural gas transportation, gas storage or distribution, and physical coal supply sources. The applicant must also affirm that it and its affiliates have not erected and will not erect barriers to entry in the relevant market.⁴

If You Fail a Screen

Failing one or both screens doesn’t automatically disqualify an applicant, because the screens create only a rebuttable presumption. The main rebuttal tool is the Delivered Price Test, a detailed economic analysis that models whether enough competing suppliers can deliver power into the applicant’s region to discipline prices. The DPT overlays generation cost data onto a transmission model to estimate how many megawatts of competing supply can reach the market at prices no more than five percent above the prevailing clearing price, examined across ten season-and-load combinations spanning summer peak, super-peak, off-peak, winter, and shoulder periods. If enough competitive supply can flow into the market even with the applicant’s capacity removed, the applicant can overcome the presumption.⁵

The DPT is expensive and data-intensive. Most applicants treat a screen failure as a serious problem worth avoiding through corporate structuring rather than a routine hurdle to clear with a fallback filing.

Category 1 vs. Category 2

FERC classifies every MBR seller as either Category 1 or Category 2 in each region where it has authority, and that classification drives how much recurring regulatory work the seller faces. A seller can be Category 1 in one region and Category 2 in another.

A seller qualifies as Category 1 in a region if it meets all of the following:⁶

A wholesale power marketer controls or is affiliated with 500 MW or less of generation in aggregate per region; a wholesale power producer owns, controls, or is affiliated with 500 MW or less in the same region as its generation assets.
The seller does not own, operate, or control transmission facilities beyond the limited equipment connecting individual generators to the grid, or it has received a waiver of the OATT requirement.
The seller is not affiliated with an entity that owns, operates, or controls transmission in the same region.
The seller is not affiliated with a franchised public utility in the same region.
The seller raises no other vertical market power issues.

A seller that misses any of these conditions is Category 2 by default. The payoff of Category 1 status is real: Category 1 sellers are exempt from filing regular updated market power analyses for the regions where they hold that designation.² Category 2 sellers must file triennial updates on a rotating FERC schedule.

What Goes in the Application

Beyond the market power analysis itself, the application requires a detailed inventory of every generation facility, long-term firm power purchase agreement, and transmission or natural gas asset owned or controlled by the applicant and its affiliates. This asset appendix is submitted in XML format into FERC’s relational database, which replaced the older spreadsheet approach.⁷ Each generator entry includes nameplate capacity, in-service date, and other identifying data.

Sellers no longer report assets owned by affiliates that hold their own MBR authority; each affiliate files its own asset appendix, and FERC’s database links them through the ownership structure narrative.⁷ That narrative must identify all ultimate upstream affiliates and, for any investors represented as passive, affirm that their ownership interests consist solely of passive rights protecting their investment rather than conferring operational control.³

The application must also include the supporting materials referenced in the indicative screens, a description of the services the seller seeks authorization to provide, and information about category status and any mitigation or other limitations.

Filing Process and Timeline

The filing begins with registering the company in FERC’s system. Applicants obtain a Company Identifier through the Company Registration page, then submit the application electronically through FERC’s eTariff system.⁸ The package includes the proposed tariff, the market power analysis, the asset appendix in XML, and the ownership structure narrative.

Under the Federal Power Act, rate schedules must be filed at least 60 days before the proposed effective date, and no more than 120 days before.⁹ If FERC takes no action within 60 days, the tariff can take effect by operation of law. In practice, the Commission typically issues an order granting or denying authority within that window. If it finds deficiencies, it may request additional information and delay the effective date, and it can suspend proposed rates for further examination.

After filing, FERC publishes a Combined Notice of Filings in the Federal Register. Competitors, consumer groups, and other stakeholders can intervene or protest during the comment period specified in the notice. Uncontested applications generally move through quickly. Contested ones can drag on considerably longer.

There are no filing fees for MBR applications, updated market power analyses, or change-in-status notices.² Public utilities that provide transmission service are subject to separate annual charges under 18 CFR Part 382.

Required Tariff Provisions

Every MBR tariff must include specific standard provisions. At minimum:¹⁰

A compliance statement committing the seller to follow 18 CFR Part 35, Subpart H, and any conditions FERC imposed in the authorization orders. Violating this provision is a tariff violation.
A seller category designation identifying the seller as Category 1 or Category 2 for each relevant region.
A list of limitations and exemptions, including any markets where the seller lacks authorization and any waivers of Commission regulations. If none exist, the seller states “none.”
Mitigated sales provisions governing sales at the boundary of a balancing authority area where the seller has been found or presumed to have market power. If a seller sells at the metered boundary of a mitigated area at market-based rates, neither the seller nor its affiliates can sell into that area from outside.

These provisions are the enforceable contract between the seller and FERC. Any noncompliance is treated as a tariff violation and carries the same consequences as violating a Commission order.

Keeping the Authority: Ongoing Filings

MBR authority does not expire, but it depends on continuous reporting. Miss a deadline and the authorization itself is at risk.²

Electronic Quarterly Reports

Every MBR seller must submit Electronic Quarterly Reports detailing each wholesale transaction, including price, volume, and delivery duration. The deadlines:¹¹

Q1 (January–March): due April 30
Q2 (April–June): due July 31
Q3 (July–September): due October 31
Q4 (October–December): due January 31

All filings are due by 5 p.m. Eastern Time. If the deadline falls on a day the Commission is closed, the due date shifts to the next business day. FERC uses the data to monitor market trends and detect anti-competitive behavior.

Change-in-Status Filings

Sellers must report any material change in the facts FERC relied on when granting MBR authority. That includes acquiring generation capacity or long-term firm purchase agreements that produce cumulative net increases of 100 MW or more in any single relevant geographic market, along with gaining ownership or control of transmission facilities or inputs to electric power production.¹²

These filings follow the same quarterly schedule as EQRs. Power sales contracts with future delivery dates become reportable once physical delivery begins. Missing a timely change-in-status filing is itself a tariff violation.¹²

Triennial Market Power Updates

Category 2 sellers must file updated market power analyses every three years on a rotating schedule set by FERC.¹³ The triennial filing essentially repeats the initial application’s analysis with current data. It includes a transmittal letter with contact information, a description of the seller’s authorized services and affiliates, updated horizontal and vertical market power representations with fresh indicative screens where necessary, and a current asset appendix.

Even a Category 2 seller that owns no assets and conducts no transactions in a region must still file the triennial for that region, marking “not applicable” in each column of the asset appendix.¹⁴ Missing a triennial is a tariff violation, and the three-year cycle makes it easy to lose track of.

Affiliate Restrictions and Anti-Manipulation Rules

When a seller with MBR authority is affiliated with a franchised public utility that has captive customers, FERC imposes strict information-sharing and conduct rules. A franchised public utility with captive customers cannot share market information with its market-regulated power sales affiliate if the sharing could harm captive customers, unless the information is simultaneously disclosed to the public. The restriction runs in both directions. Certain shared personnel — support staff, field and maintenance workers, senior officers, and board members — may access restricted information, but a no-conduit rule prevents either entity from using any person, including asset managers, to funnel restricted information between the two.¹⁵

Every MBR seller also operates under FERC’s anti-manipulation rules, which apply broadly to anyone buying or selling wholesale electricity or transmission services under the Commission’s jurisdiction. Under 18 CFR 1c.2, it is unlawful to use any scheme or device to defraud in connection with those transactions, to make materially misleading statements or omissions, or to engage in any practice that operates as a fraud or deceit.¹⁶ The rules were adopted under authority granted by the Energy Policy Act of 2005 and mirror the securities fraud provisions financial market participants know. The anti-manipulation rule does not create a private right of action; only FERC can bring enforcement actions under it.

Penalties for Non-Compliance

FERC has substantial enforcement tools, and the consequences scale with the severity and duration of the violation.

The Commission can revoke market-based rate authority outright. Revocation can be made retroactive to the date the seller first fell out of compliance, meaning every wholesale sale made during that period may be treated as unauthorized.² A seller that loses MBR authority must revert to cost-based rates, which typically produce lower margins and require detailed rate-of-return justifications for every tariff filing.

FERC can also order disgorgement of profits earned during the period of noncompliance. In determining remedies, the Commission considers whether the violation harmed the market or other participants, whether the seller self-reported promptly, whether management responsible for the violation was replaced, and whether the seller implemented new compliance procedures. Civil penalties can reach up to $1,000,000 per violation for each day the violation continues.¹⁷

Even routine procedural failures can trigger enforcement. Filing an EQR a few days late, missing a change-in-status notice, or letting a triennial deadline slip all count as tariff violations. Most sellers that run into trouble do so not because they manipulated the market, but because they lost track of a compliance deadline during a corporate reorganization or acquisition.

1
Federal Energy Regulatory Commission. Electric Market-Based Rates
2
Federal Energy Regulatory Commission. Frequently Asked Questions (FAQs) Market-Based Rates
3
eCFR. 18 CFR 35.37 – Market Power Analysis Required
4
eCFR. 18 CFR Part 35 Subpart H – Wholesale Sales of Electric Energy, Capacity and Ancillary Services at Market-Based Rates
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Federal Energy Regulatory Commission. Horizontal Market Power
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eCFR. 18 CFR 35.36 – Generally
7
Federal Register. Data Collection for Analytics and Surveillance and Market-Based Rate Purposes
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Federal Energy Regulatory Commission. Electric and MBR Step-by-Step Filing
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Federal Energy Regulatory Commission. What Do I Include in My Application? What Requirements Apply?
10
Federal Energy Regulatory Commission. Market-Based Rate Tariff Provisions
11
Federal Energy Regulatory Commission. Electric Quarterly Reports (EQR)
12
eCFR. 18 CFR 35.42 – Change in Status Reporting Requirement
13
Federal Energy Regulatory Commission. Triennial
14
Federal Energy Regulatory Commission. When and What to File
15
eCFR. 18 CFR 35.39 – Affiliate Restrictions
16
eCFR. 18 CFR Part 1c – Prohibition of Energy Market Manipulation
17
Federal Energy Regulatory Commission. Civil Penalties