U.S. AC Electric Motor Sales in Oil and Gas Market

ABB said on 20 October 2026 that “robust demand in oil & gas” lifted its Motion business, whose third-quarter orders rose 14% to USD 2.46 billion, while its United States Motion orders rose 1%, its third-quarter 2026 results show; a day later WEG reported North American external revenue up 31.1% to USD 722.8 million, naming oil and gas among the strongest users of its low-voltage motors, per its results of 21 October 2026. The U.S. alternating current (AC) electric motor sales in oil and gas market covers new induction, synchronous and permanent magnet AC motors sold to American oil and gas sites: electric submersible pump (ESP) and surface pumping motors, drilling rig and electric fracturing motors, compressor and pipeline pump motors, and refinery and petrochemical motors. Douglas Insights sizes it at USD 2.18 billion in 2025, about 112,000 motors at an average USD 19,500 each at manufacturer prices, and at USD 3.65 billion in 2035, a 5.27% compound annual growth rate (CAGR). The study sits in our oil and gas equipment and services coverage, beside the Enhanced Oil Recovery Market, 3 Phase Switched Reluctance Motor Market and Electric Control Panel Market reports, and every figure follows the Douglas Insights research methodology.

Which application carries the most AC motor value in U.S. oil and gas: artificial lift, compression, drilling or refining?

Upstream production and artificial lift carry the most, 31.0% of 2025 value or USD 677.0 million, Douglas Insights estimates. Gas compression motors grow fastest, at 6.7% a year to USD 1.04 billion by 2035.

Upstream production leads because almost every producing horizontal well in the Permian, Eagle Ford and Bakken is lifted by an ESP, a rod pump or a gas-lift compressor, and each is turned by an electric motor that fails and is replaced every 2 to 4 years, Douglas Insights estimates. American wells produced a record 13.7 million barrels a day of crude oil in 2025, and the U.S. Energy Information Administration (EIA) expects 13.9 million in 2026 and 14.3 million in 2027, its Short-Term Energy Outlook of 6 October 2026 shows. Production motors grow 5.0% a year to USD 1.10 billion as replacement cycles follow that record output.

Gas compression, USD 546.0 million, grows fastest at 6.7% because grid power lets operators replace gas engines with electric motor drive compressors at Permian and Haynesville gathering stations. Refining and petrochemicals, USD 436.8 million, grow 4.4% on pump, fan and compressor replacements at Gulf Coast plants. Drilling and completions, USD 283.9 million, grow 3.4%, the slowest, because frac activity is falling, while pipeline pumping and liquefied natural gas (LNG), USD 240.2 million, grow 6.2% as export trains add large compressor motors. Application values for 2035 sum to USD 3.65 billion, 0.14% above the USD 3.65 billion headline.

Which motor type leads: low-voltage induction, medium-voltage induction or synchronous and permanent magnet?

Low-voltage induction motors of 600 volts or less lead with 47.0% of 2025 value, about USD 1.03 billion, Douglas Insights estimates. Synchronous and permanent magnet motors grow fastest, 6.9% a year to USD 723.6 million by 2035.

Low-voltage squirrel-cage motors win on count: about 96,300 of the 112,000 motors sold in 2025, or 86%, were low-voltage units for pumps, fans, coolers and small compressors, and many carry explosion-proof enclosures for hazardous areas, Douglas Insights estimates. They grow 4.6% a year to USD 1.61 billion.

Medium-voltage induction motors, USD 786.2 million, run reciprocating and screw compressors of 1,000 to 5,000 horsepower and pipeline pumps, and grow 5.6% as electric compression spreads. Synchronous and permanent magnet machines, USD 371.3 million from only about 1,680 units, power LNG refrigerant compressors and large centrifugal compressors; Baker Hughes booked “electric motor-driven centrifugal compressors for low-pressure gas compression” in an order listed in its results of 27 October 2026. They grow 6.9% a year. Type values for 2035 sum to USD 3.69 billion, 1.10% above the headline.

What drives AC motor sales in U.S. oil and gas: Permian grid power, electric compression, record output or efficiency upgrades?

Motor units sold rise 3.0% a year in our base case, from about 112,000 in 2025 to 150,500 in 2035. Four drivers add 3.65 gross points a year; slower fracturing and dear copper remove 0.65 points.

Permian grid power replaces engines: 1.10 points

Grid power in the Permian is the largest driver, worth 1.10 points. The Electric Reliability Council of Texas (ERCOT) forecasts Permian oil and gas peak load of 11,964 megawatts in 2030 and 14,705 megawatts in 2038, within a total Permian load of 26,400 megawatts in 2038, its reliability plan updated on 25 July 2024 shows. The Public Utility Commission of Texas (PUCT) approved the plan in September 2024, at an estimated USD 13.8 billion for the 765-kilovolt option, Utility Dive reported on 27 September 2024, and authorised the first 765-kilovolt lines in ERCOT, a Texas Senate release of 25 April 2025 states. Douglas Insights estimates each 1,000 megawatts of new oilfield load connects about 1.8 million horsepower of motors at a 75% load factor.

Electric motor drive compression for record gas: 1.00 points

Electric compression adds 1.00 points. American gas output was a record 107.6 billion cubic feet a day in 2025 and EIA expects 112.2 billion in 2026, Reuters reported on 16 October 2026. Kodiak Gas Services ran about 4.5 million horsepower of compression at about 98% utilization on 30 June 2026 and cited “a tight supply environment for compression equipment” in its results of 6 August 2026. Douglas Insights estimates electric motor drive units take about 30% of new contract compression horsepower in the Permian in 2025, against about 15% five years earlier, because a motor needs no fuel gas, emits nothing on site and needs less maintenance than an engine.

Record crude output and active rigs: 0.85 points

Record output adds 0.85 points. U.S. crude production reaches 14.3 million barrels a day in 2027 in the EIA October 2026 outlook, from 13.7 million in 2025, and the Permian produced about 6.6 million barrels a day in 2025, almost half of the total, EIA’s analysis of 22 January 2026 states. The U.S. rig count held at 603 on 16 October 2026, 55 rigs or 10% above a year earlier, with 459 oil rigs and 133 gas rigs, Baker Hughes data reported by Reuters show. Douglas Insights estimates each new horizontal well adds 2 to 4 motors and each 1% rise in producing wells adds about 1,100 motor sales a year.

Efficiency upgrades and variable speed retrofits: 0.70 points

Efficiency upgrades add the last 0.70 points. From 1 June 2027 the Department of Energy (DOE) requires higher efficiency for general-purpose motors under its direct final rule of 1 June 2023, which moves mid-range motors to International Efficiency class 4 (IE4), and ABB notes a 200-horsepower motor must reach 96.2% efficiency, its guide to the 2027 standards states. Douglas Insights estimates about 9% of refinery and midstream motors older than 20 years are replaced early with IE4 motors and variable frequency drives (VFDs) by 2030. Summed, 1.10 + 1.00 + 0.85 + 0.70 = 3.65 points; after 0.65 points of headwinds the 3.0% unit leg times the 2.2% price leg gives the 5.27% revenue rate.

What holds back AC motor sales in oil and gas: slower fracturing or dear copper?

Two headwinds remove 0.65 points a year from unit growth: slower hydraulic fracturing takes 0.35 points and dear copper, which delays motor projects, takes 0.30 points, Douglas Insights estimates.

Fracturing is slowing. Halliburton’s North America revenue fell to USD 2.16 billion in the third quarter of 2026, down about 8.6% from USD 2.36 billion a year earlier and 5% from the second quarter, “primarily driven by lower pressure pumping services in U.S. Land”, its results of 20 October 2026 state; its 2027 outlook “does not require any recovery in North America hydraulic fracturing”. Electric frac fleets carry 20 to 30 large motors each, so each idle fleet removes about USD 1.5 million of motor orders, Douglas Insights estimates. Fewer new frac fleets remove 0.35 points.

Copper takes 0.30 points. A presidential proclamation of 30 July 2025 placed a 50% duty on the copper content of semi-finished copper products and intensive copper derivatives from 1 August 2025, the White House text shows, and WEG blamed higher U.S. import duties and copper costs for a gross margin of 32.9%, against 33.6% a year earlier, in its results of 21 October 2026. Douglas Insights estimates copper windings and rotor bars make up about 20% to 25% of the cost of an induction motor, so higher copper prices push some retrofits a year later.

Which region uses the most oil and gas AC motors: Permian, Gulf Coast, gas basins, Rockies or the West?

The Permian Basin uses the most, about USD 764.4 million or 35.0% of 2025 value, Douglas Insights estimates. It also grows fastest, at 6.4% a year to USD 1.42 billion by 2035, as ERCOT grid lines replace field engines.

The Permian leads because it produced about 6.6 million barrels a day in 2025, nearly half of U.S. crude, per EIA, and because its oil and gas load in the Texas portion rises from 11,964 megawatts in 2030 to 14,705 megawatts in 2038 in the ERCOT plan. ERCOT notes that transmission is “relatively sparse in the Delaware Basin subregion”, so new lines release pent-up motor installations there first. The Permian grows 6.4% a year to USD 1.42 billion.

The Gulf Coast belt from Corpus Christi to Lake Charles, USD 633.4 million, grows 4.9% on refinery motor replacements and LNG compressor trains. Appalachia and Haynesville, USD 327.6 million, grow 5.2% as gas output rises toward 112.2 billion cubic feet a day. The Rockies and Mid-Continent, USD 262.1 million, grow 3.6%, and California, Alaska and offshore platforms, USD 196.6 million, 3.3%. Regional values sum to USD 2.30 billion in 2026, 0.09% below the headline, and USD 3.63 billion in 2035, 0.44% below it.

Who supplies AC motors to U.S. oil and gas, and how concentrated is the field?

WEG holds about 15.0% of 2025 value, a Douglas Insights estimate, ahead of ABB at 14.0% and Siemens at 9.0%. The top three hold about 38.0%, and the eight companies below hold about 68.0%.

WEG, which owns the Marathon brand after buying Regal Rexnord’s industrial motors and generators business, gained most; its third-quarter release of 21 October 2026 lists oil and gas, mining and data centre cooling among the strongest outside-Brazil users of its motors, while external revenue reached a record 62.5% of its 10.86 billion Brazilian reais of net revenue, per its investor relations release. We place about USD 330 million of U.S. oil and gas motor sales with WEG. ABB’s Motion margin fell 1 point to 19.1% while revenue rose 11% to USD 2.32 billion, and it said Middle East oil and gas was weak but other markets robust, per its 20 October 2026 release.

The ESP makers buy or build their own submersible motors. Baker Hughes’ Production Solutions revenue rose 2% to USD 983 million and its North America oilfield revenue was USD 955 million in the third quarter of 2026, its 27 October 2026 release shows. Regal Rexnord, now focused on gearing and power transmission, reported Industrial Powertrain Solutions sales of USD 649.5 million, down 1.9%, with “strength in discrete automation and energy markets”, its results of 3 November 2026 state. GE Vernova, Hyundai Electric and many motor repair shops share most of the remaining 32.0%.

What does an oil and gas AC motor cost, from explosion-proof low-voltage units to large synchronous machines?

An AC motor sold to U.S. oil and gas sites costs about USD 19,500 on average in 2025 at manufacturer prices, Douglas Insights estimates, from about USD 10,700 for a low-voltage unit to about USD 221,000 for a synchronous or permanent magnet machine.

Douglas Insights splits units into three tiers: low-voltage induction motors at an average USD 10,657, with 86% of units and 47% of value; medium-voltage induction motors at about USD 56,160, with 12.5% of units and 36% of value; and synchronous and permanent magnet motors at about USD 221,000, with 1.5% of units and 17% of value. Explosion-proof enclosures for Class I hazardous areas add about 30% to 60% to a low-voltage motor’s price. The 2.2% price leg takes the average to about USD 19,929 in 2026 and USD 24,241 in 2035.

Copper, electrical steel and efficiency content set most of the price path. The 50% duty on copper content from 1 August 2025, per the proclamation, raises the cost of imported windings and motors that count as copper derivatives. Regal Rexnord booked USD 46.6 million of refunds of earlier tariffs over nine months of 2026, its 3 November 2026 release shows, which signals how much duty cost moved through motor pricing. Douglas Insights expects IE4 content to add about 0.9 points a year to the price leg to 2030, metals about 0.8 points and mix shift toward medium voltage about 0.5 points.

Which rules and standards govern oil and gas AC motors, from the DOE efficiency law to copper import duties?

Four rule sets govern these motors: DOE efficiency standards from 1 June 2027, the National Electrical Code for hazardous areas, American Petroleum Institute (API) motor specifications and the Section 232 duty on copper content.

The DOE rule covers three-phase induction motors from 1 to 750 horsepower, sets IE4 for mid-range ratings and keeps International Efficiency class 3 (IE3) for smaller and larger ones from 1 June 2027, and adds fractional motors from 1 January 2029, ABB’s guide to the Federal Register rule explains. Submersible, liquid-cooled, synchronous and inverter-only motors are exempt, so ESP motors and large synchronous compressor motors stay outside the efficiency floor. ABB cites a DOE estimate that the rule saves businesses USD 8.8 billion over 30 years.

Site rules shape the specification. Motors in oil and gas plants follow the National Electrical Code (NEC) Class I, Division 1 and Division 2 hazardous-location rules, and refiners and pipeline operators buy large motors to API 541 for induction and API 546 for synchronous machines, Douglas Insights notes from industry practice. The Section 232 copper proclamation of 30 July 2025 also set a review of refined copper by 30 June 2026, with possible duties of 15% from 2027 and 30% from 2028, the White House text states. Douglas Insights expects these rules to hold about 0.9 points a year of the price leg in efficiency content to 2030.

What if fracturing slows or grid power arrives early: how large is the market in 2035?

The market ends 2035 between USD 2.94 billion and USD 4.43 billion across three cases, around a USD 3.65 billion base. The pace of Permian grid build-out and the frac cycle set most of the spread.

In the slower case oil falls back near USD 60 a barrel, the 765-kilovolt lines slip past 2032 and fracturing keeps shrinking, taking 1.2 points off units and 1.0 point off price. In the faster case grid lines energise on time, electric motor drive units take half of new compression horsepower and copper duties widen to refined metal, adding 1.1 points to units and 0.9 points to price. One extra point of yearly revenue growth adds about USD 362 million to 2035 value, and one point less removes about USD 332 million, Douglas Insights estimates.

Live signals sit near the base case. EIA expects West Texas Intermediate at USD 88 a barrel in 2026 and USD 80 in 2027, and the rig count is 10% above a year earlier, while Halliburton’s North America revenue fell 8.6%, the sources above show. Our 5.27% sits between rising output and falling frac work.

Douglas Exclusive: the Permian Plug-In Ledger

The Permian Plug-In Ledger is a Douglas Insights model built from 12 inputs: 6 government or regulatory documents and 6 company releases. It tracks how fast grid power turns oilfield engine horsepower into AC motor orders.

The finding, a Douglas Insights estimate: ERCOT’s path adds about 2,741 megawatts of Permian oil and gas load between 2030 and 2038, about 343 megawatts a year, and a similar pace from 2025 to 2030. At 1.8 million horsepower of motors per 1,000 megawatts, that is about 615,000 horsepower of new grid-tied motors a year, worth about USD 147 million at an average USD 240 a horsepower, or 6.7% of 2025 market value. About 70% of it replaces gas engines already in the field rather than adding new wells, so grid lines, not rig counts, set most of the Permian motor curve.

The ledger changes how to read 2027 and 2028. Motor orders for compression and artificial lift follow line energisation by two to three quarters, so the first 765-kilovolt segments set a step in medium-voltage orders even if the rig count is flat. Makers with Texas stock and service shops, such as WEG, ABB and Toshiba International, capture these short-lead orders first. If the first lines energise by 2029, the base case holds; if they slip to 2032, the slower case comes closer.

How does the methodology turn 112,000 motors into USD 2.18 billion?

Our methodology multiplies about 112,000 AC motors sold to U.S. oil and gas sites in 2025 by an average manufacturer price of USD 19,500 to reach USD 2.18 billion, then grows units 3.0% and price 2.2% a year.

The model covers 5 applications, 3 motor types and 5 U.S. regions, using 58 data points, 20 sourced and 38 modelled. Units come from producing wells, rigs and frac fleets, compression horsepower, pipeline stations and refinery capacity, with replacement rates by motor class; prices come from tier mix, metals and efficiency content, all Douglas Insights estimates. Arithmetic: 112,000 x USD 19,500 = USD 2.18 billion; USD 2.18 billion x (1.030 x 1.022)^10 = USD 3.65 billion, within 0.05% of the headline. Units reach about 115,400 in 2026 and 150,500 in 2035.

Two cross-checks agree. First, our USD 330 million for WEG is about 11% of its USD 2.89 billion annualised North American external revenue in the third quarter of 2026, consistent with oil and gas as one of its leading end markets. Second, our USD 306 million for ABB is about 3.3% of its USD 9.28 billion annualised Motion revenue in the third quarter of 2026, in line with oil and gas as one of several process end markets ABB names for that business. AI tools help draft the text and automated checks test the arithmetic and links; the Douglas Insights research desk chooses the sources, builds the model and approves publication, as our editorial standards explain.

Sources

1. ABB ABB Q3 2026 results (2026)
2. WEG WEG 3Q26 results release (2026)
3. US EIA Short-Term Energy Outlook, October 2026 (2026)
4. US EIA Near-term US crude production near 2025 record (2026)
5. ERCOT Reliability Plan for the Permian Basin Region (2024)
6. Utility Dive Texas OKs Permian Basin reliability plan (2024)
7. Texas Senate PUCT approves 765 kV for the Permian (2025)
8. Reuters via BOE Report US rig count unchanged at 603 (2026)
9. Kodiak Gas Services Kodiak Gas Services Q2 2026 results (2026)
10. Halliburton (SEC) Halliburton Q3 2026 results (2026)
11. Baker Hughes (SEC) Baker Hughes Q3 2026 results (2026)
12. Regal Rexnord (SEC) Regal Rexnord Q3 2026 results (2026)
13. US DOE / Federal Register Energy conservation standards for electric motors (2023)
14. ABB Understanding the 2027 DOE motor standards (2025)
15. The White House Adjusting imports of copper into the United States (2025)

What counts in the U.S. oil and gas AC motor study, and what is excluded?

The study counts new AC induction, synchronous and permanent magnet motors sold to U.S. upstream, midstream and downstream oil and gas sites, including ESP motors, at manufacturer prices. Direct current motors, drives sold alone, motor repair and rewinds, and gas turbines are excluded.

The study splits value by 5 applications, 3 motor types and 5 U.S. regions: the Permian Basin, the Gulf Coast refining and LNG belt, the Appalachia and Haynesville gas basins, the Rockies and Mid-Continent, and California, Alaska and offshore. Motors sold inside packaged compressors and pumps count at the motor’s transfer price. Magnet-free reluctance machines are covered in our 3 Phase Switched Reluctance Motor Market report, motor control enclosures in our Electric Control Panel Market study and steam and gas injection in our Enhanced Oil Recovery Market report.