Artificial lift is the application of external energy to a producing well to supplement or replace natural reservoir drive and bring hydrocarbons to the surface at economic rates. Approximately 95% of oil wells worldwide require some form of artificial lift during their producing life. In the United States alone, over 500,000 wells use artificial lift systems, making it one of the most critical production engineering disciplines in the upstream oil and gas industry.
How It Works
When a well is first completed, reservoir pressure may be sufficient to push fluids to surface naturally — a condition known as flowing production. Over time, as pressure declines due to fluid withdrawal, the well can no longer sustain commercial flow rates. At this point, operators install artificial lift systems to reduce the hydrostatic column in the tubing, lower bottomhole flowing pressure, or physically pump fluids to surface.
The primary artificial lift methods include:
- Rod Pump (Beam Pump) — The most widely deployed system, used on approximately 80% of artificially lifted wells in the United States. Best suited for low to moderate production rates (5 to 500 barrels per day).
- ESP (Electric Submersible Pump) — A multi-stage centrifugal pump installed downhole, capable of producing 1,000 to 30,000+ barrels per day. Dominant in high-rate and offshore applications.
- Gas Lift — Injects compressed gas into the tubing annulus to reduce the density of the fluid column, allowing reservoir pressure to push fluids to surface. Effective for wells with high GOR.
- Plunger Lift — A free piston cycles inside the tubing to periodically unload liquids from gas wells. No external energy source required beyond the well's own gas pressure.
- Jet Pump — Uses high-pressure power fluid to create a venturi effect that entrains and lifts wellbore fluids. Common in deepwater completions.
Why It Matters
Artificial lift selection directly impacts production rates, operating costs, and ultimate recovery. Installing the wrong system can reduce production by 20 to 50% compared to the optimal choice, while operating costs for artificial lift typically represent 30 to 60% of total lease operating expenses. A rod pump system may cost $30,000 to $80,000 to install, while an ESP installation ranges from $80,000 to $250,000. The selection decision considers production rate, fluid properties, wellbore geometry, gas-liquid ratio, depth, power availability, and expected decline profile.
How Netora Handles Artificial Lift
Netora E&P Production provides a unified artificial lift management module that tracks rod pump, ESP, gas lift, and plunger lift installations across every well. Operators can monitor real-time performance parameters, set maintenance alerts based on run-life thresholds, and compare actual production against design rates. The system captures dynamometer cards, ESP amperage trends, and gas lift injection volumes, giving production engineers a single platform to optimize lift performance across the entire field. Learn more about Netora E&P Production.