Reservoirdruk

Reservoirdruk, or reservoir pressure, is the pressure within a hydrocarbon reservoir. It reflects the pressure state of the pore fluids in the reservoir rock and is typically expressed in bar, megapascals (MPa), or pounds per square inch (psi). The initial formation pressure is often high due to confinement of fluids under temperature and lithology, and it varies with depth, rock properties, and whether the reservoir is oil, gas, or condensate-dominated.

Reservoir pressure is a primary driving force for fluid flow toward wells. It governs production rates, water influx, gas cap movement, and the overall recovery strategy. As production continues, the pressure declines as fluids are produced and the reservoir approaches a new pressure balance. Maintaining favorable pressure through methods such as water flooding, gas injection, or other enhanced oil recovery techniques can help sustain throughput and delay productivity declines.

Measurement and estimation of reservoir pressure involve downhole pressure gauges, wireline pressure tests, and pressure transient analysis. Initial formation pressure is often estimated from early tests, logging data, and analog fields. Pressure data feed into material balance, decline-curve analysis, and reservoir simulations to estimate recoverable reserves and optimize field development planning.

In field practice, managing reservoir pressure is essential for maximizing ultimate recovery and controlling issues such as early water breakthrough and coning. The concept is central to reservoir engineering, well planning, and production forecasting, and it also informs decisions about artificial lift, injection strategies, and abandonment timing.