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Neither expanding natural-gas pipelines nor switching buildings to heat pumps is a universal winner. Pipelines add capacity to move gas through the energy system; heat pumps replace building heating equipment and increase demand on the electric grid. The better choice depends on the region, building, energy prices, existing equipment, grid resources and what costs and emissions are counted.

What is being compared—and what is not

A pipeline is shared energy infrastructure: it can transport gas for buildings, power plants, utilities and industry. A heat pump is building equipment that uses electricity to move heat, rather than producing heat by burning gas on site. Comparing the cost of a pipeline project with the purchase price of one heat pump would therefore compare different services, scales and time horizons.

A fair comparison asks what it costs to provide dependable heat to the same customers over the same period. It should include pipeline construction and financing, transportation charges, utility distribution costs and delivered gas prices on one side; on the other, heat-pump equipment and installation, any needed electrical-service upgrades, maintenance and electricity bills. It should also account for gas service, a gas line and exhaust venting that may be avoided when a building does not install gas equipment.

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Question Pipeline expansion Building heat pumps
Where the investment occurs Regional or interstate gas transportation infrastructure, with costs that may flow through contracts, tariffs and fuel prices. At individual buildings, with costs affected by equipment, installation, electrical service and any applicable incentives.
What it depends on Pipeline capacity, upstream gas supply, contracted transportation and demand from gas customers and power plants. Building conditions and equipment design, electricity supply, and generation, transmission and distribution capacity.
Comparable national lifetime cost Not stated: the reviewed sources do not provide a national, like-for-like lifetime estimate for a specified expansion. Not stated: the reviewed sources do not provide a national, like-for-like lifetime estimate for a specified deployment.
Comparable national reliability result Not stated: the sources do not provide a direct outage-performance comparison against heat-pump homes. Not stated: the sources do not provide a direct outage-performance comparison against gas-heated homes.

The available evidence combines different kinds of analysis, not a single national head-to-head test: a 2022 U.S. Energy Information Administration (EIA) pipeline scenario, 2024 U.S. Department of Energy (DOE) work and peer-reviewed building research, a December 2025 National Petroleum Council (NPC) report, and a NETL life-cycle analysis update announced in 2025. Their results answer specific questions under stated assumptions; they do not establish one national cost or reliability winner.

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What determines the cost of heat pumps and pipeline capacity?

For a home or building owner

DOE’s building-standards analysis identifies potential capital savings for electric equipment because gas-line installation and exhaust venting can be avoided. In some cases, the analysis also finds that higher electricity costs relative to gas can raise building-owner costs. These are conditional findings, not a universal verdict on bills: the outcome depends on local rates, equipment and installation costs, the building’s heating and cooling needs, and what equipment is being replaced.

Replacing both a gas furnace and central air-conditioning can change the comparison because one heat-pump system may provide both heating and cooling. A peer-reviewed study of Los Angeles buildings found its most favorable modeled heat-pump replacement case among owners replacing both systems. That finding applies to the study’s location, building sample, prices and technology assumptions; it should not be treated as a forecast for every building.

For pipeline customers and energy systems

Pipeline investment is regional. Construction and financing costs, transportation contracts, utility charges, gas supply and local demand all affect who pays and what the infrastructure changes. A new line’s project cost alone does not reveal the change in a household’s delivered-fuel bill or the value of capacity to a utility or power generator.

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In its 2022 Annual Energy Outlook (AEO2022), EIA modeled a case that restricted unplanned interstate pipeline builds after 2023, comparing it with a reference case. The scenario projected changes in pipeline capacity, gas supply and prices, and power generation through 2050, with different outcomes by region. It is not a forecast for a particular proposed pipeline, a current universal cost estimate, or a direct comparison with a specified heat-pump rollout.

Incentives and who pays

The Los Angeles study modeled Inflation Reduction Act rebate assumptions under which high-efficiency heat pumps could be a net-savings option for many qualifying owners and landlords. Eligibility and actual savings depend on current program rules, local costs and the building; check the applicable incentive and utility requirements rather than assuming a modeled rebate is available to a particular project.

Costs can also land differently on landlords and tenants. In the same study, renters could face higher operating costs if landlords chose electric resistance heating, which has lower landlord capital costs than a high-efficiency heat pump. A landlord’s equipment decision and a tenant’s utility bill are therefore not necessarily aligned. The study’s findings are specific to its modeled Los Angeles conditions, not a universal estimate of renter bills.

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How reliable is each option?

Gas delivery is not independent of the electric grid

Gas infrastructure can supply direct building heat and fuel gas-fired power plants. Delivery depends on pipeline capacity, upstream supply and transportation arrangements, while power-sector demand can affect the same system. The NPC’s December 2025 report describes constraints and coordination needs between gas and electricity systems. It also says pipeline expansion financing depends on firm, long-term transportation contracts, reflecting an investment model oriented around contracted demand. The report focuses on natural-gas infrastructure operations and coordination; it is not an independent head-to-head reliability study of gas heating and heat pumps.

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Heat pumps depend on buildings and the electric system

A heat pump requires electricity, so dependable heat depends on more than the equipment itself. Building thermal performance, correct system sizing and design matter alongside generation adequacy, transmission, local distribution capacity and utility planning for cold-weather and other peak periods. Weatherization, appropriate backup options and demand-response programs can be relevant implementation choices, but the reviewed sources do not establish that any one measure guarantees service during an outage.

DOE’s 2024 transmission assessment treats a robust transmission system as important for grid needs and load growth, including electrification. Its modeled scenarios find that sharing reliability resources across broader regions can reduce costs and outage risk. That is a regional transmission finding—not proof that transmission alone resolves local distribution constraints or that the assessment modeled a specific heat-pump deployment.

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The evidence does not establish a universal reliability winner or provide a direct outage-performance comparison between homes heated by heat pumps and those heated by gas. A local assessment should consider the building, utility plans, expected peak demand and available backup arrangements rather than treating either appliance or pipeline capacity as a complete measure of resilience.

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What do the emissions and environmental comparisons show?

A lifecycle comparison should not count only gas burned in a furnace or power plant. It can include gas extraction and processing, transport, pipeline construction and end use, as well as electricity used by heat pumps and the generation mix supplying that electricity. NETL’s life-cycle assessment methodology also considers emissions to air and water, water use and land use. Its updated report represents 2020 U.S. natural-gas supply using several data sources, including EPA inventory data and measurement-based studies. The electricity mix varies by place and can change over time, so the result depends on both the boundary and the grid serving the building.

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EIA’s AEO2022 restricted-pipeline scenario illustrates why limiting gas infrastructure does not translate mechanically into an equal reduction in emissions: less gas-fired generation was partly replaced by other sources, including coal. In the modeled 2050 case, EIA projected:

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  • 201 billion kilowatt-hours, or 10.8% less natural-gas-fired generation than in its reference case.
  • 34 million metric tons, or 0.7%, lower total energy-related carbon dioxide emissions than in its reference case. EIA attributed the modest overall difference in part to higher coal generation replacing some gas-fired generation.

Both figures describe EIA’s 2022 scenario comparison for 2050, not measured outcomes or a heat-pump deployment case. They show that the power-sector response matters when evaluating a pipeline constraint; they do not establish the lifecycle emissions of a particular pipeline project or heat-pump installation.

DOE’s 2024 enhanced regional and interregional transmission deployment scenario projected $320 billion in present-value costs saved through 2050 and 3,420 million metric tons of cumulative power-sector greenhouse-gas emissions reduced through 2050. Those are modeled transmission-scenario results, not standalone heat-pump savings or emissions reductions. They indicate the potential value attributed to a broader grid scenario, not a direct comparison with pipeline expansion.

The reviewed evidence does not supply a single national, like-for-like lifecycle-emissions estimate comparing a specified amount of pipeline expansion with a specified number and type of heat-pump installations. Nor does it quantify one universal local air-pollution outcome for that comparison. A useful local assessment needs to specify the project, building and equipment, electricity mix, fuel-supply assumptions and lifecycle boundary.

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Quick Recap

How to make a location-specific decision

  1. Define the service and time horizon. Compare the cost and reliability of providing heat to the same buildings and customers over the same period, rather than setting a pipeline project budget beside an appliance price.
  2. Use local cost inputs. For a building, gather installed equipment quotes, any electrical-service work, maintenance expectations, gas and electricity tariffs, and costs avoided by not installing or retaining gas service. For a pipeline proposal, identify its financing and cost-recovery arrangements, transportation contracts, utility charges and customers expected to use the capacity.
  3. Check the building and grid constraints. Assess building thermal performance and system sizing alongside utility generation, transmission and local distribution plans for peak conditions. A regional transmission analysis cannot substitute for checking a specific service area or property.
  4. Confirm incentive eligibility and bill responsibility. Verify current programs for the project and location. For rentals, identify who pays for equipment and who pays the energy bill, since those incentives can differ.
  5. State the environmental boundary. Include fuel supply, infrastructure and end use, and identify which electricity generation mix serves the heat pump. Do not assume that gas combustion alone or a fixed national grid mix represents the full lifecycle result.

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