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Coal gasification and conventional coal combustion are different power-plant routes, and the 2022 National Energy Technology Laboratory (NETL) baseline does not show gasification as automatically more efficient, cleaner, or cheaper. In that modeled comparison, integrated gasification combined cycle (IGCC) plants delivered 39.9%–43.0% net higher-heating-value (HHV) efficiency without carbon capture, while supercritical pulverized coal (PC) delivered 40.2%. The least-cost no-capture IGCC case had a modeled levelized cost of electricity (LCOE) of $103.2/MWh, versus $64.5/MWh for supercritical PC, both in real 2018 dollars and excluding carbon-dioxide transport and storage.
IGCC did have lower modeled gross CO2 and SO2 intensity in those cases. Those figures are controlled, plant-level model outputs—not lifecycle emissions, current market bids, or a guarantee for every gasifier, coal type, or operating plant. The direct comparison below uses NETL’s 2022 baseline, because its 2025 Volume 1 overview lists pulverized-coal and natural-gas combined-cycle configurations but does not list IGCC.
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| Name | Best for | Key spec | Checked |
|---|---|---|---|
| IGCC (coal gasification) | Projects that value syngas cleanup, fuel flexibility or a capture-ready process and can support higher capital cost | 39.9%–43.0% net HHV efficiency without capture; $103.2/MWh least-cost no-capture LCOE in NETL’s model | November 2026 |
| Supercritical pulverized coal | Conventional coal generation seeking the lower modeled cost in the cited baseline | 40.2% net HHV efficiency without capture; $64.5/MWh no-capture LCOE in NETL’s model | November 2026 |
Prices checked November 2026.
All figures in the table come from NETL’s 2022 modeled bituminous-coal baseline. Costs are real 2018 dollars, and the LCOE figures exclude CO2 transport and storage.
What is the difference between coal gasification and conventional coal combustion?
Conventional pulverized-coal generation burns finely ground coal directly in an air-fired boiler. The boiler’s heat turns water into steam, and that steam drives a turbine-generator. A supercritical PC plant raises steam above the critical point of water to improve the steam cycle’s efficiency, but it remains a combustion-and-steam system.
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IGCC takes a different route. A gasifier reacts coal with a controlled amount of oxygen and steam instead of fully burning it. The result is synthesis gas, or syngas, containing mainly hydrogen and carbon monoxide plus contaminants that must be removed. Cleaned syngas fuels a gas turbine; its hot exhaust also produces steam for a bottoming steam turbine. That combined-cycle arrangement is why the relevant comparison is net electricity from the entire plant, after pumps, oxygen production, gas cleanup, cooling and other auxiliary loads—not the efficiency of the gasifier alone.
NETL’s 2022 Cost and Performance Baseline models those complete plant configurations. Comparing only the fuel-conversion step can make gasification appear better than it is at the generator terminal, because oxygen plants, syngas treatment and compression consume substantial power.
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Not consistently. NETL’s no-capture cases range from 39.9% to 43.0% net HHV efficiency for IGCC, compared with 40.2% for supercritical PC. The range crosses the PC result: the modeled Shell configuration is highest, while other IGCC configurations are below or near the PC case.
| Configuration | Net efficiency, no CO2 capture (HHV) | How to read it |
|---|---|---|
| IGCC cases | 39.9%–43.0% | Performance varies by gasifier and plant configuration |
| Supercritical PC | 40.2% | Single modeled reference case in the same baseline |
These are modeled net efficiencies, not measurements of every operating plant. HHV (higher heating value) is the fuel-energy basis used by the study; using a lower-heating-value result from one source against an HHV result from another would create a misleading comparison. Net output also matters: a plant that generates more gross power but consumes more electricity internally can have a lower net efficiency.
The main engineering trade-off is familiar from combined-cycle design. IGCC can extract power through both a gas turbine and a steam cycle, but it must first make oxygen, gasify the coal, cool and clean the syngas, and manage ash and sulfur compounds. Those steps add equipment and parasitic load. A particular gasifier, heat-integration scheme or coal feed can therefore move the result above or below a conventional supercritical boiler.
What happens to efficiency when carbon capture is added?
Both routes lose net efficiency when a nominal 90% CO2-capture system is included. NETL’s modeled IGCC configurations fall to 30.2%–33.8% net HHV efficiency, while the supercritical PC case falls to 31.7%.
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| Configuration | Net efficiency with nominal 90% capture (HHV) | Approximate loss from its no-capture case |
|---|---|---|
| IGCC cases | 30.2%–33.8% | About 6–10 percentage points, depending on gasifier and capture configuration |
| Supercritical PC | 31.7% | About 8–9 percentage points in the modeled case |
NETL attributes the IGCC penalty mainly to steam extraction for the water-gas-shift reaction, electricity for CO2 separation and compression, and derating associated with syngas moisture. In practical terms, capture equipment takes heat and power that would otherwise become saleable electricity. A capture percentage is therefore not a free add-on to the plant’s original output.
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“Nominal 90%” is a modeled design target, not proof that every hour of operation will remove exactly 90% of total plant emissions. Capture rates, availability, solvent or sorbent performance, compression energy and the definition of the emissions boundary all affect the result. The residual-emissions figures below should be read in that context.
Does IGCC produce fewer emissions than a conventional coal plant?
In NETL’s modeled cases, yes for the reported gross CO2 and SO2 intensities. That does not mean gasification eliminates pollution or is lower for every pollutant and every lifecycle boundary.
Modeled gross CO2 intensity
| Case | IGCC | Supercritical PC |
|---|---|---|
| No capture | 1,328–1,396 lb/MWh | 1,628 lb/MWh |
| Nominal 90% capture | 151–163 lb/MWh | 187 lb/MWh |
These are gross-output stack intensities from the modeled cases, as reported in NETL’s environmental analysis. They are not lifecycle numbers. Mining, coal transport, construction, upstream methane, ash management, plant replacement and CO2 transport or storage are outside what these particular intensity figures establish. Do not silently convert them into emissions per net MWh or compare them with a lifecycle figure from another study.
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Modeled gross SO2 intensity
| Case | IGCC | Supercritical PC |
|---|---|---|
| No capture | 0.015–0.192 lb/MWh | 0.649 lb/MWh |
IGCC removes sulfur compounds from syngas before combustion, while PC plants remove sulfur from flue gas after combustion. The modeled IGCC range is wide. NETL identifies the E-Gas configuration using refrigerated methyl diethanolamine (MDEA) as the highest-SO2 IGCC case because its modeled hydrogen-sulfide-removal efficiency was lower than that of the other acid-gas-removal technologies. That detail matters: “gasification” is not a single emissions-control design.
NETL reports that the modeled criteria-pollutant controls meet or fall below the regulatory limits applied in its study. A permit decision still requires a project-specific emissions inventory, applicable jurisdictional limits, stack testing requirements and operating assumptions. The baseline does not establish compliance for an unbuilt plant.
Are the emissions figures lifecycle emissions?
No. The headline CO2 and SO2 numbers are modeled plant-level, gross-output stack intensities. They are useful for comparing the cited configurations under a common boundary, but they cannot answer a full lifecycle question by themselves.
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For a lifecycle comparison, define whether the boundary includes coal extraction, transport, upstream fuel processing, construction materials, water infrastructure, ash disposal, carbon-dioxide pipelines and storage, and decommissioning. Also specify whether the denominator is gross generation, net generation delivered to the grid, or useful energy. A study that changes any of those choices can report a different intensity without either study being arithmetically wrong.
For construction or investment decisions, request the emissions boundary in the same schedule as the performance guarantee. “CO2 per MWh” is incomplete unless the contract states the output basis, fuel specification, capture rate, auxiliary-load treatment and operating condition.
Why do gasifier choice and coal quality change the result?
Gasifier configuration controls how coal is fed, how heat is recovered, how syngas is cooled and how contaminants are removed. NETL’s modeled no-capture results illustrate that spread: the Shell case reaches 43.0% net efficiency, the two-stage E-Gas case reaches 41.1%, and the GEP cases are lower in the same study.
Coal properties matter even more for IGCC than for many PC comparisons. The Massachusetts Institute of Technology’s Future of Coal report explains that IGCC performance and capital cost are more sensitive to coal quality. High ash, high moisture and low heating value can challenge slurry-fed gasifiers; dry-feed systems may suit some high-moisture fuels better. That report was published in 2007, so use it as engineering context rather than as a current universal ranking of gasifiers.
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Before selecting a process, characterize the actual fuel: as-received moisture, ash fusion behavior, sulfur, heating value, trace elements and expected variability. Then require the vendor’s guaranteed net output and emissions at those fuel conditions, not only at a laboratory reference coal. A plant optimized for one feedstock can lose efficiency or availability when the mine blend changes.
Is IGCC cheaper than a conventional coal plant?
Not in NETL’s cited no-capture baseline. The least-cost modeled IGCC configuration has an LCOE of $103.2/MWh, compared with $64.5/MWh for supercritical PC. Those are real 2018-dollar values from a standardized model, not current bids, tariffs or consumer electricity prices.
| Metric | IGCC | Supercritical PC |
|---|---|---|
| No-capture LCOE | $103.2/MWh for the least-cost modeled case | $64.5/MWh |
| Dollar basis | Real 2018 dollars | |
| Included in comparison | Capital, operations and fuel under NETL’s financing assumptions | |
| Excluded | CO2 transport and storage | |
NETL defines LCOE as the revenue required per net megawatt-hour to cover capital, operating and fuel costs under the study’s financing assumptions. IGCC’s higher value reflects the additional gasification, oxygen-production, syngas-cleanup and combined-cycle equipment in the modeled configuration. Capture cases cost more than their respective no-capture cases because capture, compression and associated energy penalties add capital and operating requirements.
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The comparison is intentionally standardized: greenfield plants at a generic Midwestern U.S. site, a 30-year life, an 80% capacity factor for IGCC and 85% for PC. Change the capacity factor, coal price, financing rate, construction conditions, schedule, labor cost, incentives or carbon policy and the LCOE changes. A lower-utilization plant spreads fixed costs over fewer megawatt-hours; a site with unusual water, oxygen or transmission requirements can move the result in either direction.
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Use the NETL figures as a transparent reference point, not as a turnkey budget. A defensible comparison should keep the following items aligned:
- Net output basis: Compare net MW and net MWh after all auxiliary loads. Confirm whether oxygen production, CO2 compression, cooling and wastewater treatment are inside the fence line.
- Fuel specification: Use the same coal moisture, ash, sulfur, heating value and blend range for both alternatives. Ask for guaranteed performance at the worst credible feed, not only the design-point fuel.
- Capture boundary: State the capture percentage, whether it is on total or process CO2, compression pressure, transport distance and storage assumptions.
- Emissions basis: Label every value as gross or net output and as stack, site-wide or lifecycle. Keep CO2, SO2, particulate matter, nitrogen oxides, mercury and solid residues in separate lines.
- Financial basis: Put the dollar year, escalation method, discount rate, construction schedule, capacity factor and financing structure next to every LCOE or capital-cost number.
- Availability and maintenance: Require assumptions for planned outages, gasifier availability, boiler or turbine derating, spare trains and startup fuel. A nominal efficiency advantage is not valuable if the plant cannot deliver its contracted net output.
- Site infrastructure: Check oxygen supply, water, coal handling, slag or ash disposal, sulfur-product handling, transmission interconnection and, for capture, CO2 pipeline and storage access.
This checklist is particularly important when comparing a new-build IGCC proposal with a conventional boiler. The technologies do not have identical equipment lists, construction sequences or commissioning risks, so a simple “efficiency minus cost” ranking can conceal major scope differences.
How current is the direct IGCC-versus-PC evidence?
The direct quantitative comparison in this article is the 2022 NETL baseline. NETL’s baseline overview published for 2025 lists six pulverized-coal and nine natural-gas combined-cycle configurations, but it does not list IGCC among those configurations. That omission does not prove that IGCC technology has disappeared or that every newer project would perform worse; it means the 2022 study should remain visibly dated rather than being presented as a 2025 or 2026 market forecast.
NETL describes the baseline as a consistent basis for comparing developing technologies and setting research and development goals. It is valuable for isolating process differences under common assumptions, but it is not a survey of every operating plant, a current procurement quote or a forecast of retail electricity prices. Current project economics require a new, site-specific model.
What is the practical verdict for builders and owners?
Choose IGCC when the project has a specific reason to accept its added complexity—such as an engineered syngas and contaminant-removal scheme, a capture and compression plan, or a fuel-handling strategy that fits the selected gasifier. Do not choose it merely because “combined cycle” sounds more efficient than a steam plant: the modeled no-capture range straddles the supercritical-PC result.
Choose conventional supercritical PC when the priority in the cited baseline is lower modeled LCOE and a familiar boiler-and-flue-gas-control arrangement, while recognizing that it still has high CO2 output without capture and incurs a substantial efficiency penalty when capture is added.
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For either route, the right decision depends on the project boundary. Normalize net output, coal quality, capacity factor, emissions controls, capture scope, financing and dollar year before comparing proposals. The strongest conclusion supported by the evidence is conditional: IGCC can reduce modeled stack CO2 and SO2 intensity in the specified cases, but it is not categorically more efficient or cheaper than conventional coal combustion.
How we picked the comparison criteria
The comparison uses the criteria that determine whether a coal-power claim is genuinely like-for-like: net HHV efficiency, gross-versus-net emissions boundaries, gasifier and coal characteristics, carbon-capture assumptions, capacity factor, LCOE dollar year, and whether CO2 transport and storage are included. The numerical ranges come from NETL’s 2022 modeled baseline; coal-quality context comes from MIT’s Future of Coal report; and environmental-control context comes from NETL’s gasification environmental study at netl.doe.gov.
Bottom line: which route wins?
Neither route wins on every measure. In NETL’s 2022 model, IGCC’s best configuration reaches higher net efficiency than the PC reference and all modeled IGCC cases have lower gross CO2 and SO2 intensity, but IGCC efficiency spans both sides of the PC result and its least-cost no-capture LCOE is substantially higher. Carbon capture lowers net efficiency and raises cost for both. Treat the figures as a dated, controlled engineering comparison and rebuild them with site-specific fuel, finance, infrastructure and emissions boundaries before making a construction decision.
Frequently Asked Questions
Why does the HHV basis matter when comparing coal-plant efficiency?
Higher heating value includes the latent heat recovered when water in the combustion products is condensed. A percentage reported on an LHV basis will generally look different from an HHV percentage, so both plants must use the same heating-value convention before the numbers are compared.
Does lower modeled SO2 mean an IGCC plant has no sulfur-management problem?
No. Sulfur still enters with the coal and must be removed, handled and either sold or disposed of. The modeled range shows that acid-gas-removal technology and configuration affect residual SO2; it does not remove the need for sulfur balances, equipment maintenance and permitting.
What does a nominal 90% carbon-capture rate leave out?
It describes the modeled capture target for the defined CO2 stream, not necessarily 90% of every greenhouse-gas source across the mine-to-storage lifecycle. Startup, shutdown, bypass operation, solvent condition, compression outages and uncaptured process or combustion streams can change actual plant-wide performance.
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Why can two LCOE studies give different answers for the same technology?
LCOE is highly sensitive to capacity factor, financing assumptions, construction schedule, fuel price, labor and materials, plant life and carbon or tax policy. A study using a different dollar year or including transport and storage is answering a different cost question, even if both calculations are internally consistent.
Can the 2022 NETL numbers be used as a current construction bid?
No. They are standardized modeled estimates in real 2018 dollars for a generic Midwestern site. A current bid needs site-specific engineering, a defined coal supply, updated financing and commodity prices, firm equipment quotations, interconnection costs and a documented carbon-transport and storage plan.
