Oil & Gas Pipeline Regulation

The United States has approximately 2.5 million miles of pipeline carrying natural gas, oil, and hazardous liquids — the most extensive pipeline system in the world — regulated by a split federal authority: the Pipeline and Hazardous Materials Safety Administration (PHMSA) governs pipeline safety under 49 U.S.C. §§ 60101–60141, setting design, construction, testing, and inspection standards; the Federal Energy Regulatory Commission (FERC) regulates the rates and certification of interstate natural gas pipelines under the Natural Gas Act (15 U.S.C. §§ 717–717z), with the power to approve or deny the construction of major new pipeline infrastructure. Pipeline safety became a major public issue after the San Bruno, California gas explosion (2010) — which killed 8 people and destroyed 38 homes — revealed systemic failures in PG&E's pipeline inspection records, prompting major PHMSA rule upgrades requiring operators to conduct integrity management programs and verify the specifications of aging pipelines. The East Palestine, Ohio train derailment (2023) — though a rail accident, not a pipeline — intensified scrutiny of all hazardous materials infrastructure and prompted emergency rulemaking. Major pipeline projects (Keystone XL, Dakota Access, Mountain Valley Pipeline) have become flashpoints in the broader fossil fuel vs. climate policy debate, with FERC's "certificate of public convenience and necessity" process and NEPA environmental review creating years-long approval timelines and litigation risk. Pipelines that cross international borders require Presidential Permits, a power the Biden administration used to revoke the Keystone XL permit on its first day in office (2021).

Current Law (2026)

Legal Authority

• 49 U.S.C. § 60102 — Pipeline safety standards (Secretary of Transportation shall prescribe minimum safety standards for pipeline transportation and facilities; standards must be practicable and designed to protect people and property)
• 49 U.S.C. § 60109 — High-consequence areas (pipeline operators must identify high-consequence areas — populated areas, drinking water sources, ecological resources — and implement integrity management programs with enhanced inspection and maintenance)
• 15 U.S.C. § 717f — FERC certificate for natural gas pipelines (no person shall construct or extend interstate natural gas pipeline facilities without a certificate of public convenience and necessity from FERC; certificate authorizes construction and grants eminent domain authority)
• 49 U.S.C. § 60117 — PHMSA enforcement (inspections, investigations, civil penalties up to $257,664 per violation per day; maximum $2,576,627 for a related series of violations)

How It Works

America's pipeline network is one of the largest infrastructure systems in the world — over 3 million miles of natural gas pipelines and 225,000 miles of oil and hazardous liquid pipelines, transporting the fuels that power the economy. Pipeline regulation involves two distinct systems: PHMSA regulates safety, and FERC regulates the economics of interstate natural gas transportation.

Pipeline safety is regulated by the Pipeline and Hazardous Materials Safety Administration (PHMSA) within DOT, which sets and enforces minimum safety standards for all pipelines — natural gas transmission and distribution, oil, and hazardous liquids. Key requirements include integrity management programs requiring inspection and testing of pipelines in high-consequence areas (near populated areas, drinking water sources, or environmentally sensitive areas); leak detection and repair requirements; emergency response plans; public awareness programs in pipeline communities; and operator qualification standards for pipeline workers. PHMSA conducts inspections, investigates incidents, and assesses civil penalties; state pipeline safety agencies inspect approximately 80% of natural gas distribution pipelines under delegated federal authority. Despite this oversight, PHMSA reports 600–700 significant incidents annually — fatalities, injuries, fires, and explosions — with high-profile events including the San Bruno gas pipeline explosion (2010, 8 deaths) and the Colonial Pipeline ransomware attack (2021, multi-state fuel shortage). Many pipeline segments are 50–70+ years old, making aging infrastructure a persistent concern.

Building a new interstate natural gas pipeline or LNG terminal requires a certificate of public convenience and necessity from FERC — one of the most consequential and contested federal permitting processes. The certificate process requires demonstrating market demand through shipper contracts, completing an Environmental Impact Statement under NEPA, considering alternatives, and evaluating landowner and community impacts through public comment and hearings. Once FERC issues a certificate, the pipeline company receives federal eminent domain authority — the right to condemn private land for the right-of-way — making FERC pipeline certification intensely controversial when projects cross agricultural land, sensitive ecosystems, or opposing communities. Oil pipeline rates are regulated by FERC under the Interstate Commerce Act and the Energy Policy Act of 1992; most rates are set using an indexing methodology, adjusted annually by an inflation index rather than traditional cost-of-service ratemaking. LNG export terminals require authorization from both FERC (siting and construction) and DOE (export authorization); U.S. LNG export capacity has expanded dramatically since 2016, making the U.S. one of the world's largest LNG exporters.

How It Affects You

State Variations

Implementing Regulations

• 18 CFR Part 153 — LNG terminal facilities (pre-filing procedures for import/export facilities)

• 18 CFR Part 157 — Applications for Certificates of Public Convenience and Necessity under Section 7 of the Natural Gas Act (47 sections — the procedural framework for authorizing new natural gas pipeline capacity, LNG terminals, and storage facilities, as well as abandonment of existing facilities). Section 7 of the NGA prohibits interstate natural gas companies from constructing or operating new facilities, or abandoning existing service, without FERC authorization. Key provisions:

  • § 157.21 — Pre-filing procedures for major projects: for large pipeline expansions, LNG terminals, and other significant facilities, FERC requires a pre-filing environmental review process at least 6 months before the formal certificate application; the pre-filing process involves consultation with agencies, tribes, and affected communities before the formal NEPA environmental review begins; the pre-filing docket number (PF) is assigned before the formal CP docket
  • § 157.14 — Required exhibits: certificate applications must include detailed technical and financial information — maps of the proposed route, engineering design specifications, environmental studies (wetlands, threatened species, cultural resources), financial statements, market demand studies showing shipper need, and rate analysis; the exhibit requirements can run to thousands of pages for major pipeline projects
  • § 157.10 — Interventions and protests: any person wishing to participate in a FERC certificate proceeding must file a motion to intervene within the period specified in FERC's notice (typically 21 days from the notice); intervenors become parties with rights to participate in hearings and seek rehearing and judicial review; environmental organizations, landowners, and competing pipeline companies commonly intervene in certificate proceedings
  • § 157.20 — General conditions applicable to certificates: all pipeline certificates include standard conditions — the company must begin construction within the time specified or the certificate lapses; the pipeline must be completed and placed into service within specified deadlines; FERC retains continuing jurisdiction over the certificated facilities and can impose additional conditions
  • § 157.201–157.203 — Blanket certificate program: holders of interstate pipeline certificates may obtain a "blanket certificate" authorizing routine construction, acquisition, and operation of facilities below specified cost thresholds without filing individual project applications; a blanket certificate covers activities up to $11.2 million (prior notice required) or $3.2 million (automatic authorization); this streamlines routine capacity maintenance while preserving FERC review for significant expansions
  • § 157.208 — Construction, acquisition, and replacement under blanket: the most-used blanket certificate authorization; covers routine pipeline construction, compression additions, meter stations, and replacement of existing facilities; projects above the automatic authorization threshold require prior notice to FERC and affected parties; objections can escalate to full certificate proceedings
  • § 157.212 — LNG and synthetic gas facilities: construction and operation of LNG liquefaction, storage, or regasification facilities on interstate pipelines must receive separate FERC authorization even under blanket certificates for certain thresholds; major LNG export terminal projects (e.g., Sabine Pass, Freeport LNG) require individual Section 7 certificates with full environmental impact statements under NEPA
  • § 157.18 — Abandonment applications: a pipeline company wishing to abandon certificated facilities or service must obtain FERC approval; customers with firm service contracts have the right to challenge abandonment; FERC weighs continued need against the pipeline's economic justification for abandonment; "permanent" abandonment requires decommissioning the facilities
  • § 157.17 — Emergency temporary certificates: FERC may issue temporary emergency certificates without prior notice and comment in cases where the delay would cause immediate public harm or supply disruptions; temporary certificates were used frequently after Hurricanes Katrina and Rita and during the 2021 Texas winter storm

  The Section 7 certificate process is the central regulatory bottleneck for new natural gas infrastructure in the United States. A major interstate pipeline project typically takes 3-5 years from pre-filing through final certificate to construction — driven primarily by NEPA environmental review timelines, litigation challenging environmental impact statements, and agency coordination requirements. The Biden administration's 2022 policy statement (later withdrawn) would have required pipelines to demonstrate actual contracts as evidence of need rather than relying on affiliated shipper precedent agreements. The Trump administration's January 2025 executive order directing FERC to streamline gas infrastructure permitting generated significant controversy about how much executive authority can direct FERC's independent regulatory processes.

• 18 CFR Part 260 — Natural Gas Company Statements and Reports: FERC's mandatory financial and operational reporting requirements for jurisdictional natural gas companies and pipelines. These forms are the transparency and accountability mechanism that enables FERC to monitor financial condition, market activity, and system integrity of the regulated pipeline industry. Key provisions:

  • § 260.1 — FERC Form No. 2 (Annual Report for Major Natural Gas Companies): Class A and Class B natural gas companies (as defined by the Natural Gas Act) must file the comprehensive Form 2 annual report with FERC; the form includes financial statements (income statement, balance sheet, statement of cash flows), plant-in-service schedules (the rate base underlying FERC-approved tariffs), operating statistics, and gas supply data; this is the primary financial transparency document for interstate pipelines
  • § 260.2 — FERC Form No. 2-A (Annual Report for Nonmajor Natural Gas Companies): smaller natural gas companies file the abbreviated Form 2-A; the filing threshold distinguishes nonmajor companies (below the Class A/B revenue threshold) from those required to file the full Form 2
  • § 260.300 — FERC Form No. 3-Q (Quarterly Financial Report): electric utilities, hydroelectric licensees, and natural gas companies must file quarterly financial reports covering each calendar quarter; the 3-Q provides FERC with current financial condition data between annual Form 1/Form 2 filings, enabling monitoring of mid-year financial deterioration or significant capital events
  • § 260.400 — Cash management programs: natural gas companies subject to FERC's Uniform System of Accounts (18 CFR Part 201) that participate in inter-affiliate cash management or money pool arrangements must file those agreements with FERC; cash management transparency prevents ratepayers from bearing costs of imprudent inter-affiliate lending and cross-subsidization
  • § 260.401 — FERC Form No. 552 (Annual Report of Natural Gas Transactions): all natural gas market participants — including interstate pipelines, LDCs, and marketers — must annually report the price, volume, and counterparty information for their gas purchases and sales; Form 552 provides FERC's market monitoring unit with data to detect price manipulation and assess market concentration
  • § 260.8 — System flow diagrams (Format FERC 567): each Major natural gas pipeline company with system delivery capacity exceeding 100,000 Mcf/day must file annual system flow diagrams showing points of supply, delivery, interconnection, and storage; the diagrams enable FERC and the public to visualize pipeline system topology
  • § 260.9 — Service interruption and facility damage reports: every natural gas company must immediately report damage to jurisdictional facilities and service interruptions to FERC's pipeline division; timely interruption reporting is essential for FERC's emergency coordination role during extreme weather events (the 2021 Texas winter storm and 2022 Freeport LNG outage generated extensive §260.9 reports that shaped FERC's subsequent cold-weather reliability rulemaking)

  FERC's Form 2 and Form 3-Q data are publicly available in FERC's electronic library and form the empirical basis for rate cases, market power analyses, and pipeline financial monitoring. State utility commissioners, shippers, and intervenors in FERC rate proceedings routinely use Form 2 data to challenge pipeline cost allocations and rate base claims. The Form 552 gas transaction reporting has been central to FERC's market manipulation investigations — the data enables reconstruction of trading patterns around price index manipulation (as in the FERC investigations following the 2000-2001 California energy crisis).

• 18 CFR Part 284 — Certain Sales and Transportation of Natural Gas Under the Natural Gas Policy Act of 1978 and Related Authorities (58 sections — the FERC open-access transportation framework that unbundled interstate natural gas pipelines beginning in 1992). Key provisions:

  • § 284.1 — Definitions: "transportation" encompasses storage, exchange, backhaul, displacement, and other indirect movement methods — not just physical flow
  • § 284.10 — Rates: all rates for open-access transportation under the Part must be filed with FERC before taking effect; ad hoc or negotiated rates outside a filed tariff are prohibited
  • § 284.11 — Environmental compliance: any activity involving facility construction or abandonment with removal under the Part triggers NEPA environmental review
  • § 284.12 — NAESB business standards: interstate pipelines providing open-access service must incorporate North American Energy Standards Board (NAESB) operating and communications standards — the technical backbone of electronic gas trading
  • § 284.13 — Reporting requirements for interstate pipelines: pipelines providing open-access service must report capacity, nomination, and flow data on a publicly accessible website (the basis for the FERC gas data portal)
  • § 284.14 — Posting requirements for major non-interstate pipelines: large intrastate pipelines must post daily capacity and flow information publicly
  • § 284.15 — Affiliate bidding in open seasons: multiple affiliates of the same entity may not bid against each other in pipeline open seasons for capacity — an anti-gaming rule protecting independent shippers
  • § 284.101–284.102 — Section 311(a) interstate-for-intrastate transportation: any interstate pipeline may, under a blanket FERC authorization, transport gas on behalf of intrastate pipelines and their customers — this provision enabled the development of the spot market in natural gas
  • § 284.121–284.124 — Section 311 intrastate pipelines: intrastate pipelines may transport gas for interstate pipelines and local distribution companies; rates must be "fair and equitable" per FERC review; terms must make the arrangement subject to FERC jurisdiction during the transaction
  • § 284.221–284.224 — Blanket certificates for open-access transportation: any interstate pipeline may apply for a single blanket certificate authorizing all open-access transportation services under the Part; once issued, the certificate eliminates the need to seek transaction-specific approval for each shipper arrangement; local distribution companies served by interstate pipelines may also provide transportation for their own customers under this subpart

  Part 284 is the regulatory foundation of the modern U.S. natural gas market. FERC's Order No. 636 (1992) required interstate pipelines to "unbundle" — separating the sale of gas from its transportation — and made open-access transportation under Part 284 the default operating mode for all interstate pipelines. Before unbundling, pipelines both owned gas and controlled access to transportation; after Order 636, pipelines became common carriers obligated to transport any shipper's gas under non-discriminatory rates. The result was the creation of thousands of trading points (hubs), the Henry Hub price benchmark, and the U.S. natural gas futures market. Every time a gas producer, utility, or industrial buyer negotiates pipeline capacity, their contract rights and the pipeline's obligation to transport are governed by the filed tariff authorized under Part 284.

Pending Legislation

• HR 6187 — Grants, stronger testing/notices, penalties, trust fund for hazardous liquid pipeline safety modernization. Status: Introduced.
• HR 8050 — Require gas utilities to identify risky vintage plastic pipes, no-dig assessments within 3 years. Status: Introduced.
• S 2975 (Sen. Cruz, R-TX) — Modernize pipeline safety, raise PHMSA funding, confidential data-sharing system. Status: In committee.
• HR 5537 (Rep. Trahan, D-MA) — CO2 rules, 30-minute rupture isolation mandates, public disclosure, grants for non-emitting alternatives. Status: In committee.
• S 2905 (Sen. Markey, D-MA) — Tighten pipeline safety standards, public disclosure, CO2-specific rules, community engagement funding. Status: Introduced.
• HR 5301 (Rep. Graves, R-MO) — Expand pipeline safety to CO2 pipelines, raise PHMSA funding/grants, tighten penalties and inspections. Status: In committee.
• HR 4818 (Rep. Peters, D-CA) — Make PHMSA gas pipeline leak detection rule effective immediately. Status: In committee.
• S 2508 (Sen. Lujan, D-NM) — Make PHMSA gas pipeline leak detection/repair rule effective on enactment. Status: Introduced.
• HR 3948 (Rep. Brownley, D-CA) — Tighten offshore pipeline inspections, per-mile owner fees, pipeline removal studies. Status: Introduced.
• HR 3488 (Rep. Carbajal, D-CA) — Extend valve-installation and rupture-detection standards to Type A gas gathering lines. Status: In committee.
• HR 3231 — American Energy Act: would speed federal oil and gas permitting by fixing permit terms and restricting court orders. Status: Introduced.
• HR 3061 — BRIDGE Production Act: would require 26 offshore lease sales over 10 years and streamline environmental reviews. Status: Introduced.
• HR 1274 — Protecting American Households From Rising Energy Costs Act: would bar most U.S. LNG and petroleum exports to entities tied to China, Russia, Iran, and North Korea. Status: Introduced.

Recent Developments

• Pipeline permitting reform remains a major political issue, with proposals to streamline FERC certification timelines while maintaining environmental review
• PHMSA has strengthened safety standards for high-consequence areas and imposed new leak detection requirements for methane emissions
• The Colonial Pipeline cyberattack (2021) highlighted cybersecurity vulnerabilities in pipeline systems, prompting new TSA security directives
• Pipeline rights-of-way on federal lands are governed by the Mineral Leasing Act. LNG export policy is contested — DOE paused new export authorizations in 2024 for climate review, then resumed under court order and policy changes. See also Fossil Fuel Policy and Outer Continental Shelf for the broader oil and gas production framework
• Aging pipeline infrastructure nationwide requires billions in replacement and rehabilitation investment