Gas lift is an artificial-lift method that adds energy to a well not by pumping, but by injecting compressed gas into the fluid column to make it lighter and easier for reservoir pressure to lift. It is a favorite for high-rate, gassy, and deviated wells - and for offshore, where gas is available and downhole pumps are costly to service. This guide explains how gas lift works and where it fits.
Gas Lift in one line: Gas lift is an artificial-lift method that injects compressed gas into the production tubing to reduce the density of the fluid column, so the well's own pressure can lift the lighter mixture to the surface. It uses no downhole moving parts.
A well's fluid column has weight, and that weight is the back-pressure the reservoir must overcome to flow. Gas lift injects gas into the tubing so the produced fluid becomes a lighter gas-liquid mixture; the lighter column exerts less back-pressure, and the reservoir can then push the well to surface at a higher rate. It is aeration, not pumping.
Injection gas is compressed at surface and sent down the tubing-casing annulus. It enters the tubing through gas lift valves mounted in side-pocket mandrels at set depths. On startup, the upper valves unload the well progressively until gas is injected at the deepest point of injection, where it does the most good.
In continuous gas lift, gas is injected steadily to keep the column aerated - suited to wells with reasonable inflow that benefit from a constantly lighter column. In intermittent gas lift, a slug of gas is injected periodically to push a liquid slug to surface, then the well builds back up - suited to lower-productivity wells, and conceptually similar to plunger lift.
Gas lift has real strengths: no downhole moving parts to fail, tolerance of sand and high gas-oil ratios, effectiveness in deviated wells, and easy rate adjustment from surface. Its requirements are a source of compressed gas and enough reservoir pressure to respond to the lighter column.
Key data include injection gas rate and pressure, casing (injection) pressure, tubing (production) pressure, and produced rates. Watching these together shows whether gas is entering at the intended valve, whether the well is stable or heading, and whether the injection rate is optimized - too little gas underlifts, too much wastes compression and can increase friction.
SCADA gathers injection and production data from field instruments and controllers. A cloud platform such as Merobix reads injection controllers and meters over Modbus, so gas lift injection rates and pressures across a field are visible and can be optimized remotely.
It injects compressed gas into the production tubing so the fluid becomes a lighter gas-liquid mixture. The lighter column exerts less back-pressure, letting the reservoir's own pressure push the well to surface at a higher rate. It lightens the column rather than pumping.
A gas lift valve is a pressure- or fluid-operated valve set in a side-pocket mandrel on the tubing at a specific depth. It admits injection gas from the annulus into the tubing. Upper valves unload the well on startup until gas is injected at the deepest point of injection.
Continuous gas lift injects gas steadily to keep the column aerated, suited to wells with decent inflow. Intermittent gas lift injects gas in periodic slugs to push liquid to surface, then lets the well build back up, suited to lower-productivity wells.
This page references the protocol specifications published by the organizations below. Editions, product capabilities, and documentation change over time - confirm current requirements and specifications directly with the source.
Last reviewed: July 27, 2026. Merobix is not affiliated with, endorsed by, or sponsored by these organizations; their names are used only to identify the standards and products discussed.
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