To start a power company you choose one of three business models (generator, retail provider, or integrated utility), clear the federal and state approvals that attach to that model, secure grid interconnection and environmental permits if you are building physical assets, and set up a compliance program before your first sale. The Federal Energy Regulatory Commission governs wholesale electricity sales and interstate transmission; state public utility commissions govern retail sales and local distribution.1Office of the Law Revision Counsel. 16 USC 824 – Declaration of Policy; Application of Subchapter How much time you spend with each regulator depends entirely on which model you pick.
Pick Your Business Model First
The electricity supply chain splits into three roles. Where you enter sets your capital needs, your regulator, and your day-to-day work.
Independent power producers build and operate generating facilities (natural gas plants, wind farms, solar arrays) and sell electricity into the wholesale market. They do not own wires and do not deal with homeowners. FERC is the primary regulator. Revenue comes from contracts with utilities and other wholesale buyers. This is the most capital-intensive model because physical infrastructure, environmental permits, and interconnection agreements all come before the first sale.
Retail electric providers buy electricity at wholesale prices and resell it to homes and businesses. They handle billing, customer acquisition, and plan design without owning generation or transmission equipment. The model only works in deregulated states where consumers can choose their supplier. Roughly 18 jurisdictions, including Texas, Illinois, Pennsylvania, Ohio, and New York, currently allow retail competition. The capital bar is lower than for generation, but you still need state licensing, surety bonds, and proof of creditworthiness.
Vertically integrated utilities own everything from the plant through the transmission lines down to the meter. They hold a monopoly in an assigned service territory and face heavier regulatory scrutiny because of it. State commissions set their rates, and major investments must be justified through rate cases. New entrants rarely start here because territories are already claimed, though acquisitions and municipal utility formations still happen.
Know Which Regulator You Answer To
The federal-state split is the organizing principle. FERC has jurisdiction over wholesale electricity sales (any sale of power for resale) and transmission of power across state lines.2Federal Energy Regulatory Commission. Energy Markets State public utility commissions handle retail rates, local distribution, and licensing of retail providers. Sell at wholesale and you answer to FERC. Sell to consumers and your state commission is the gatekeeper.
Texas is the big exception. The ERCOT grid is not interconnected with other states, so wholesale sales within ERCOT fall outside FERC jurisdiction entirely.3Federal Energy Regulatory Commission. An Introductory Guide to Electricity Markets Regulated by the Federal Energy Regulatory Commission A generation company operating only inside ERCOT follows a different path from one connecting to PJM or MISO.
Most organized wholesale markets are run by Regional Transmission Organizations or Independent System Operators. To participate, your company typically has to become a member or market participant of the relevant RTO or ISO, which involves application fees and ongoing dues. Annual membership fees at major RTOs run roughly $5,000 to $15,000 depending on the organization and category.
Prove You Can Run It
Regulators will not take your word for financial stability, management competence, or site control. These are the gating items.
Financial Assurance and Bonding
States licensing retail electric providers commonly require surety bonds to protect customers if the provider defaults. Bond amounts of $250,000 per license type are common, though some states scale the amount to projected customer load or revenue. Generators seeking wholesale market-based rate authority from FERC must show financial viability in the application, though FERC does not set a fixed minimum capitalization threshold.
If your company will sit inside a holding company structure, expect additional scrutiny under the Public Utility Holding Company Act of 2005. That statute gives FERC authority to examine the books, accounts, and records of any company in a holding company system when relevant to the rates charged by a utility affiliate.4Office of the Law Revision Counsel. 42 USC 16452 – Federal Access to Books and Records The purpose is to stop a parent from loading costs onto a regulated subsidiary and passing them to captive ratepayers. Plan to keep detailed intercompany transaction records from day one.
Management and Technical Capacity
Regulators review the resumes of your management team and key operational staff. For a generator, that means demonstrated expertise in load forecasting, plant operations, and emergency response. For a retail provider, it means a credible plan for billing systems, customer complaint handling, and supplier contracts. Applications have been rejected where the management team lacked relevant industry experience.
Site Control for Generators
Building a plant means proving you have legal rights to the land. That is deeds, leases, or option agreements for the generation site. Under FERC’s reformed interconnection process, you need at least 90% site control when you submit your interconnection request and 100% site control by the time you execute a facilities study agreement.5Federal Energy Regulatory Commission. Explainer on the Interconnection Final Rule The rule was written specifically to clear speculative projects out of the interconnection queue.
Environmental Permits for Generation
This is where generation projects slip. Building a plant triggers federal and state environmental review that can take months or years.
Any project requiring a federal permit, using federal land, or receiving federal funding must comply with the National Environmental Policy Act. The responsible federal agency evaluates environmental impacts, resulting in a categorical exclusion for low-impact projects, an environmental assessment for moderate ones, or a full environmental impact statement for major facilities. The level depends on the project.
New fossil fuel plants need Clean Air Act permits. Major sources require a Prevention of Significant Deterioration or New Source Review permit before construction, plus a Title V operating permit before operations begin. These involve emissions modeling, public comment, and often negotiation over pollution control technology. For a natural gas combined-cycle plant, the air permits alone can take 12 to 18 months.
Water use and discharge permits under the Clean Water Act, stormwater permits, and state environmental reviews add further layers. Wetlands, endangered species habitat, or cultural resources on the site trigger more federal consultations. Underestimating environmental permitting is one of the most common reasons generation projects stall after significant capital has already been spent.
File for Wholesale Selling Authority
If you plan to sell at wholesale, you almost certainly want market-based rate authority from FERC rather than cost-based rates. Market-based rates let you sell at prices set by supply and demand; cost-based rates cap your revenue at documented production costs plus a regulated return. To get market-based rate authorization, you file an application showing that you and your affiliates lack, or have adequately mitigated, both horizontal and vertical market power.6Federal Energy Regulatory Commission. Frequently Asked Questions (FAQs) Market-Based Rates
FERC classifies sellers into two categories. Category 1 sellers are wholesale power marketers or producers affiliated with 500 MW or less of generation in a region, with no affiliations with transmission owners or franchised utilities in the same region.7eCFR. 18 CFR 35.36 – Generally Everyone else is Category 2, which requires more detailed market power analysis including delivered price tests and market share screens. Most small new entrants qualify as Category 1.
The centerpiece of the filing is the Asset Appendix, an inventory of every generation asset, long-term power purchase agreement, and vertical asset (transmission facilities, natural gas pipelines, storage) owned or controlled by you or any affiliate.6Federal Energy Regulatory Commission. Frequently Asked Questions (FAQs) Market-Based Rates You also submit a complete organizational chart showing every entity under common ownership. Before filing the application itself, you submit baseline data into FERC’s online MBR Database.
FERC charges no filing fee for market-based rate authority applications.6Federal Energy Regulatory Commission. Frequently Asked Questions (FAQs) Market-Based Rates Other FERC filings do carry substantial fees. Qualifying facility certification runs $36,160 to $40,940 depending on the facility type, and declaratory orders cost $42,060.8Federal Register. Annual Update of Filing Fees State retail licensing fees are much lower, generally a few hundred dollars for the application itself, with surety bond costs on top.
Connect to the Grid
Owning a plant means nothing if you cannot connect it. The interconnection process was historically a years-long bottleneck, and FERC overhauled it with Order 2023.
Transmission providers now group interconnection requests into clusters for study rather than processing them one at a time.5Federal Energy Regulatory Commission. Explainer on the Interconnection Final Rule Each cluster runs through a 150-day cluster study followed by a facilities study, after which you sign an interconnection agreement. The cluster approach is faster than serial processing, but your project’s timeline depends partly on who else is in your cluster.
FERC also imposed stiff financial requirements to discourage speculative queue entries. You pay a study deposit based on the megawatt size of your facility when you submit your request. As the project advances, you owe commercial readiness deposits that increase at each stage, calculated as a percentage of your share of identified network upgrade costs.5Federal Energy Regulatory Commission. Explainer on the Interconnection Final Rule Withdrawing from the queue in a way that materially affects other projects triggers withdrawal penalties. These deposits are large enough to belong in your business plan as capital, not overhead.
Network upgrade costs are allocated among the projects in your cluster using a proportional impact method. A 50 MW solar farm causing $2 million in transformer upgrades bears a different share than a 200 MW gas plant in the same cluster triggering separate line upgrades. Understanding potential upgrade costs before you file your interconnection request is essential. Network upgrade obligations have killed otherwise viable projects.
How Approval Actually Happens
Federal applications go through FERC’s electronic filing system. You create an account through the eRegistration portal, which gives you access to eFiling for uploads.9FERC Online. FERC Online Help – Account Access and Creation State submissions vary; most commissions accept electronic filings, though some still require paper copies by certified mail.
Once FERC receives your application, it assigns a docket number that becomes the permanent identifier for your case. Within about a week, a notice of filing appears in the Federal Register. For market-based rate applications, the comment period is typically around 21 days from the notice date, not the 60-day window that applies to some other FERC proceedings such as preliminary hydropower permits.10Federal Energy Regulatory Commission. Preliminary Permits – Filing Comments, Motions to Intervene, and Competing Applications
During the comment period, anyone with a direct interest can file a motion to intervene. That includes competitors, consumer advocates, state commissions, and federal agencies. The intervenor must show a statutory right to participate, a direct interest that may be affected, or that participation serves the public interest.11eCFR. 18 CFR 385.214 – Intervention (Rule 214) If no one opposes a timely motion within 15 days, the intervenor automatically becomes a party.
If a substantive protest is filed, FERC may assign an administrative law judge to hold hearings and gather evidence. Timeline implications are significant. Straightforward market-based rate applications with no opposition often receive approval within 60 days. Contested proceedings or complex generation projects can take well over a year. Plan financing and construction around that reality.
What You Owe After Approval
Getting approved is not the finish line. Build staff time and systems for ongoing reporting from day one.
Every seller with market-based rate authority files Electric Quarterly Reports summarizing all wholesale transactions (contract terms and actual transaction data). They are due four times per year: April 30 for Q1, July 31 for Q2, October 31 for Q3, and January 31 for Q4, each by 5 p.m. Eastern Time.12Federal Energy Regulatory Commission. Electric Quarterly Reports (EQR) Missing a deadline or filing inaccurate data can trigger enforcement.
Larger utilities file FERC Form No. 1, the annual report for major electric utilities. You qualify as “major” if, in each of the three previous calendar years, your total annual sales exceeded one million megawatt-hours, your annual wholesale sales exceeded 100 megawatt-hours, or your annual wheeling or power exchange deliveries exceeded 500 megawatt-hours.13Federal Energy Regulatory Commission. Form No. 1 – Annual Report of Major Electric Utility New entities expecting to cross those thresholds should begin filing based on projected data.
If you own generation assets connected to the bulk electric system, you must register with the North American Electric Reliability Corporation as a Generator Owner and possibly a Generator Operator. For non-bulk-electric-system inverter-based resources such as solar and battery storage, mandatory registration kicks in at an aggregate nameplate capacity of 20 MVA or more connected at 60 kV or above.14NERC. Appendix 5B – Statement of Compliance Registry Criteria Larger dispersed resources aggregating above 75 MVA at 100 kV or above face Category 1 registration. Registration brings mandatory compliance with NERC reliability standards, including the Critical Infrastructure Protection cybersecurity standards. Even low-impact facilities must maintain documented cyber security plans covering electronic access controls, physical security, incident response, and malicious code mitigation for portable devices.
If you certified your facility as a qualifying small power production or cogeneration facility under PURPA, maintaining that status requires ongoing conformity with FERC’s criteria. If your facility stops conforming with the material facts in your certification, QF status can be revoked.15eCFR. 18 CFR 292.207 – Procedures for Obtaining Qualifying Status Before making any substantial alteration to a certified QF, apply to FERC for a determination that the changes will not trigger revocation. Losing QF status retroactively can unwind favorable purchase contracts with utilities.
State Renewable Mandates Shape Your Market
Twenty-eight states and the District of Columbia have enacted renewable portfolio standards requiring utilities and retail providers to source a minimum percentage of electricity from renewable sources. Seventeen of those jurisdictions have set targets of 100% renewable or clean electricity by 2050 or earlier.16U.S. Energy Information Administration. Renewable Energy Explained – Portfolio Standards If you are launching a retail provider, you will need to procure renewable energy certificates or contract with renewable generators to meet your state’s requirement. If you are building generation, these mandates create built-in demand for renewable energy credits from wind or solar projects. Factor the RPS landscape into your market analysis before committing to a fuel source or target market.
Enforcement Exposure Starts On Day One
FERC’s enforcement arm has real teeth, and new participants are not exempt. Under FERC’s anti-manipulation rule, it is unlawful to use any scheme to defraud, make any materially misleading statement, or engage in any practice that operates as fraud in connection with the purchase or sale of electricity or transmission services subject to FERC jurisdiction.17Federal Energy Regulatory Commission. Prohibition of Energy Market Manipulation That covers wash trading, strategic withholding of capacity to inflate prices, and similar conduct.
The financial exposure is large. For violations of Section 316A of the Federal Power Act, the inflation-adjusted maximum civil penalty is $1,584,648 per violation, per day.18Federal Register. Civil Monetary Penalty Inflation Adjustments FERC applies the maximum penalty in effect at the time of assessment, regardless of when the violation occurred. For other Federal Power Act provisions, penalties reach $28,618 per violation per day. FERC has assessed nine-figure penalties against energy companies for market manipulation. Build a compliance program before you start trading, not after you receive an enforcement letter.