The debates: bridge or lock-in, cold snaps, and gas versus storage

A few arguments run under almost every fight over a new gas plant or pipeline. Is gas a bridge to a cleaner grid or a trap that keeps us burning it for decades? Can gas be counted on when the weather turns brutal? And is gas still the cheapest way to keep the lights on when the sun is down and the wind is still, or have batteries caught up? Each side has real evidence. Anyone taking part in one of these fights should know the strongest version of each case and where the evidence settles the matter.

Bridge fuel or lock-in

The strongest case for gas as a bridge

The US cut power sector CO2 a great deal after 2008, and gas replacing coal did much of that work. EIA's numbers show why: gas plants emit 0.96 pounds of CO2 per kWh versus coal's 2.31. Gas plants also emit far less sulfur dioxide, mercury and soot, which matters for public health near plants. Supporters, including most utilities, the gas industry, many grid operators and some energy economists, add that a grid with lots of wind and solar needs flexible backup that can run for days, and gas is the proven, available option. Building gas now, they argue, lets coal retire sooner and lets renewables grow without risking blackouts. Some new plants are being designed to burn hydrogen blends later or to add carbon capture, which supporters cite as a path to lower emissions over the plant's life.

The strongest case for lock-in

A combined-cycle plant is built to run 30 to 40 years, and its cost is usually recovered from customers over a similar period. A plant approved in 2026 could still be running in 2066. Opponents, including many climate scientists, environmental groups and some state energy agencies, argue that once customers are paying for a plant, regulators and utilities face heavy pressure to keep running it, and shutting it early leaves customers with stranded costs. They point to methane leakage, which narrows the climate gap with coal (lesson 6), and to measurement studies like Sherwin and colleagues in Nature (2024), which found leak rates about three times the government inventory. And they note that hydrogen and carbon capture at gas plants remain mostly unbuilt at commercial scale, so promises of later conversion should be weighed as plans, not facts.

Where the evidence points

The historical record supports the bridge argument for gas replacing coal: CO2 fell. Whether new gas in 2026 is a bridge depends on what it replaces and how long it runs. A gas plant that lets a coal plant retire early cuts emissions. A gas plant built to serve new load, such as a data center, adds emissions unless something else is retired. Both sides often blur that difference. Ask which one it is.

Reliability in cold snaps

Gas is sold as reliable, dispatchable power. The two worst US winter grid events in recent memory both involved gas failing in large numbers. Neither side's favorite version of these events matches the federal record.

Winter Storm Uri, February 2021

Extreme cold hit Texas and the south-central US. ERCOT ordered 20,000 MW of rolling blackouts, the largest manually controlled load shed in US history per FERC. More than 4.5 million people in Texas lost power, some for up to four days. Texas's state health department put the final death toll at 246; some independent analyses of excess deaths estimated considerably more. The joint FERC-NERC report found that gas-fired units were 58% of generating units with outages, derates or failures to start. Freezing problems caused 44.2% of outages and fuel problems 31.4%. Gas production fell sharply as wellheads and gathering equipment froze, and some gas equipment itself lost power during the blackouts, making the fuel shortage worse.

Wind turbines also froze. ERCOT data reported by Power Engineering showed about 27 GW of gas capacity lost, out of about 52 GW of total generating capacity lost, with wind, coal and nuclear units also failing. Early political claims blaming frozen wind turbines for the blackouts did not match the data; gas was the largest single source of lost power. Claims that renewables played no role were also wrong.

Winter Storm Elliott, December 2022

Elliott hit the eastern US on December 21 to 26, 2022. FERC and NERC reported unplanned outages peaking at 90,500 MW, with more than 127,000 MW unavailable counting units already out. Grid operators shed a combined 5,400 MW, the largest controlled load shed in Eastern Interconnection history. Of the 1,702 affected generating units, 47% were gas, 21% wind, 12% coal, 3% solar, under 1% nuclear and 17% other. Causes: mechanical and electrical failures (41%), freezing (31%) and fuel problems (24%). Gas fuel problems alone were 20% of all lost megawatts. Marcellus production fell 23% and Utica 54% from freeze-offs.

Measure	Uri (Feb 2021)	Elliott (Dec 2022)
Controlled load shed	20,000 MW (ERCOT)	5,400 MW (several operators)
Gas share of affected units	58%	47%
Freezing as a cause	44.2%	31%
Fuel supply as a cause	31.4%	24%
Deaths	246 in Texas (state estimate)	Not a single official total for the grid event

What each side takes from this

Gas supporters argue the problem is fixable: winterize wells and plants, secure firm pipeline capacity, add backup fuel oil at plants, and coordinate gas and electric operations. FERC approved mandatory NERC cold-weather standards after Uri, and Texas passed winterization laws. Critics argue that gas and electric systems depend on each other in a way that makes cold snaps a shared point of failure: cold drives heating demand up and gas production down at the same time, and pipelines are not built to the same reliability standards as the grid. Both points stand. Gas is dispatchable when the fuel shows up, and the fuel did not reliably show up in either storm.

Gas versus storage

Batteries now do jobs gas used to own. EIA's count of planned 2026 additions included 24 GW of batteries and 6.3 GW of gas. The comparison depends on which job.

Resource (Lazard 2025, unsubsidized)	Cost range	Best job	Limits
Gas combined cycle	$48 to $109/MWh	Running most hours, multi-day firming	Fuel price risk, emissions, turbine backlog
Gas peaker	$149 to $251/MWh	Rare peak hours, multi-day backup if fueled	High cost per MWh at low hours, emissions
Battery, 2-hour (LCOS)	$81 to $174/MWh	Short peaks, frequency response	Short duration
Battery, 4-hour (LCOS)	$145 to $319/MWh	Evening ramp, daily solar shifting	Empty after 4 hours at full output

Lazard's figures leave out tax credits, fuel price assumptions in some comparisons, carbon costs and differences in financing, so they are a starting point. Levelized costs also miss what each resource adds to reliability, which is why grid planners use separate measures, such as how much each megawatt counts toward meeting a peak.

The strongest case for gas here is duration: a fueled gas plant can run for days, and nothing else as cheap and available today can. The strongest case for storage is that it is cheaper for the hours it covers, has no fuel price exposure, can be built in a year or two while gas turbines are backlogged for years (GE Vernova reported 116 GW of backlog and reservations in mid-2026), and gets cheaper over time. Both are true, which is why the answer in most places is a mix and the fight is over the proportions.