Case Studies

A major carbonate field with 53 producers and 45 injectors had been under waterflooding since the 1950s. In the mid-1990s, Water-Alternating-Gas (WAG) was introduced to improve sweep efficiency. Despite decades of operation, suboptimal injector performance and inefficient gas allocation limited oil recovery.

The Umm Shaif Field, operated by ADNOC, is an offshore asset with complex reservoir heterogeneities and a mix of oil and gas development challenges. Traditional full-physics reservoir simulations for field development planning (FDP) were taking 9–12 months, limiting the ability to evaluate multiple scenarios and reducing decision-making confidence.

ADNOC’s WAG injection operations required validation of CRM connectivity analysis against full-physics forecasts. A key challenge was that simulation forecasts often start from a BHP-controlled state rather than the field’s true operational regime, leading to unrealistic production trends and limiting the reliability of direct well-by-well comparisons.

ADNOC sought to optimize waterflood management and field development planning (FDP) across multiple reservoirs. Traditional approaches—manual pattern analysis and full-physics simulation—took 6–18 months and limited the ability to evaluate multiple scenarios, slowing optimization and reducing confidence in well and injection planning decisions.