Electric Submersible Pumps (ESP) Market Size & Share Analysis - Growth Trends and Forecast (2026 - 2031)

Global Electric Submersible Pumps (ESP) Market Trends and Insights

Onshore Location of Deployment to Dominate the Market

• The onshore oil and gas sector accounts for the largest share in the electric submersible pumps market. In 2020, the average global onshore rig count reached 843 rigs, representing a decrease of almost 51.5% from 1,629 in 2019 over the previous year. This was primarily due to production cut by OPEC plus and reduction in prices of oil; however, with the increase in prices, the number of ESPs is set to increase, especially on the onshore deployment, as they require fewer prices to be profitable.
• Also, a growing focus on heavy oil reservoirs, coupled with the requirement of ESP systems in shale reservoirs, is expected to drive business growth.
• The marginal/stripper wells, which produce less than 10 barrels of oil or 60,000 cubic feet of natural gas per day, require additional technological aid to increase their production. Factors such as the increasing number of marginal and stripper wells and the growing demand to produce oil at the minimum cost are likely to drive the demand for ESPs in the coming years.
• Increasing adoption of new technologies is also expected to aid the market. For instance, in December 2021, Brunei Shell Petroleum Company and AccessESP completed a trial project using GoRigless ESP System technology. The GoRigless ESP System is a slickline-retrieval technology for AccessESP high-performance permanent magnet motors and industry-standard ESP pumps. It avoids the cost and complexity of a heavy workover rig required for traditional tubing-deployed ESP system interventions.
• Therefore, the increase in the number of wells drilled, along with the demand for low-cost production solutions, is expected to augment the demand for ESPs in the onshore sector over the forecast period and keep it as the dominant location of deployment in the forecast period.

North America to Dominate the Market

• In 2021, North America was estimated to be the largest market among the regions studied. This is primarily due to the shale gas plays in the United States, which have supported the country to become the largest producer of crude oil in the world.
• The oil and gas industry in the United States is projected to provide a huge impetus to the ESP market on account of widespread investments lined up in oil and gas projects for the coming years.
• According to Baker Hughes, as of February 2022, 753 rigs were online in the country, with the Permian Basin having the largest share. These wells are expected to be completed in the coming years, creating ample instances for the usage of ESPs system suppliers in the forecast period.
• On the other hand, In Canada, the sand oil available is of high density and has high sand particle content, due to which oil transport from the bottom hole of the oil well to the surface requires high pressure. Hence, there is high demand and, in turn, assistance from artificial lifts. However, the usage of electric submersible pumps (ESP) for pumping the sand oil is very difficult due to the oil's high viscous nature. This, in turn, is expected to limit the demand for ESP in Canada.
• On the Mexican side of the Gulf of Mexico (GoM), PEMEX has made several discoveries. PEMEX has issued contracts for the development of these fields. Hence, in the long run, the demand for electric submersible pumps is likely to emanate from this region.
• Hence, the region is expected to dominate the market due to the type of crude oil produced in the region and the large-scale deployment of private investment to develop the wells.

Regulatory Landscape

Electric submersible pump (ESP) design and qualification increasingly point to formal equipment standards and regulated operating requirements across key producing regions. ISO 15551:2023 sets requirements for the design, verification/validation, manufacturing, and data control of tubing-deployed ESP systems, which provides a common framework used in procurement and quality assurance for global deployments. In offshore US operations, compliance obligations also extend into project execution and operations control documentation, including requirements under 30 CFR 250.875 for subsea pump systems to align with approved development and operations coordination documentation.

Environmental and facility oversight policies also influence ESP selection, monitoring, and site practices. In the United States, EPA rules targeting oil and natural gas sector emissions, including 40 CFR Part 60 Subpart OOOOb, tighten expectations for methane/VOC control for equipment at production sites, which can drive upgrades that reduce fugitive emissions and improve integrity management. At the state level, California Public Utilities Commission actions such as Resolution ESRB-13 (General Order 167-C) reinforce maintenance and operational standards for electric generating facilities and energy storage. Similar safety and network management rulemaking activity in Australia (New South Wales, 2026 Regulatory Impact Statement for the Electricity Supply (Safety and Network Management) Regulation) highlights continued attention on electrical safety compliance relevant to ESP-associated surface power and control infrastructure.

Value Chain Analysis

The ESP value chain spans upstream materials and specialized electrical components through integrated system assembly and lifecycle services. Key inputs include high-strength and corrosion-resistant alloys for pump stages and shafts, specialized cables, motors (induction and permanent magnet), and surface control equipment such as variable frequency drives and digital surveillance software. System design, integration, and qualification are typically carried out by major oilfield service providers and OEMs (including SLB, Baker Hughes, and Halliburton) together with specialized manufacturers (including Borets and Novomet), with configuration and testing tied closely to well conditions such as depth, temperature, solids, and gas fraction, as well as intervention constraints.

Downstream, the chain is increasingly service-led, with providers packaging equipment supply alongside installation, monitoring, optimization, repair, and workover support, often under multi-year agreements that emphasize uptime. Recent industry actions reflect this bundling trend, including Baker Hughes work that integrates automation platforms (Leucipa) with ESP hardware under multi-year supply frameworks, and SLB introductions that pair compact ESP systems with live surveillance and production optimization. Bottlenecks tend to cluster around high-performance motors and power cables, as well as regional localization needs that move assembly, repair, and test capacity closer to operating basins to shorten lead times and meet in-country value expectations.

Market Opportunities and Future Outlook

Incremental value in ESP programs is increasingly linked to reliability, flow assurance, and automation, not pump hardware alone, creating room for solutions that reduce failure drivers in gassy, scaled, corrosive, or HPHT wells. In 2026, SLB released an autonomous chemical optimization approach for ESPs that digitalizes workflows using edge and cloud intelligence to manage flow assurance and asset integrity risks. This is aligned with operator needs to reduce intervention frequency and stabilize run life. Field validation activity is also moving beyond monitoring into closed-loop control, including a data-driven model predictive control (DDMPC) approach reported for subsea ESP operations that improved production while maintaining safety constraints, reinforcing the shift toward performance-managed artificial lift.

Motor efficiency and intervention logistics are additional opportunity areas where operator programs and field studies show traction. Petroleum Development Oman has implemented machine-learning-based predictive failure detection workflows for ESP wells, indicating practical readiness to operationalize predictive analytics in daily lift management. Separately, field work in the Gulf of Thailand highlighted efficiency gains from permanent magnet motor ESPs versus induction motor designs, supporting adoption where power consumption and diesel logistics are material cost and emissions levers. Rigless and rapid-deployment concepts, including cable-deployed and tubing-retrievable approaches validated in the field, also broaden the addressable set of mature and constrained wells by reducing non-productive time and limiting reliance on heavy workover equipment.