The Mangala field in the Rajasthan state of western India was the first major oil discovery in the Barmer Basin having a STOIIP of over 1.3 billion barrels in multiple stacked fluvial clastic reservoirs. It contains medium gravity (20-28 °API), waxy, viscous crude (9-17 cp) in high permeability (1-25 Darcy) clean sandstone reservoirs. Mangala field is on production since 2009 and is currently producing at 150k bopd.
The field has a comprehensive reservoir Management plan (RMP). As per the RMP, an active reservoir surveillance plan of data acquisition and analysis is being continuously executed in the field. The key data acquisition included Pressure surveys, Production and injection logging, well and network modeling, Reservoir saturation logging, Interference testing, well & artificial lift parameters.
Several challenges and production and injection problems were identified and were addressed in a step wise manner. The well and reservoir performance for ∼ 2 years suggested higher production capacity. Detailed well modeling and surface network modeling was carried out and it was seen that after the installation of Artificial lift, the ongoing production enhancement efforts, continuous reservoir surveillance and management, the field had capacity to produce at a plateau rate of 150k bopd. Simulation studies suggested no detrimental effects on the ultimate recovery.
The plateau rate of the field was increased from approved FDP rate of 125k to 150k bopd, after due approvals and the field has been producing at this rate since April 2012. This paper presents the summary of:
Data acquired during the production phase of 125k bopd
Major problems identified in the field and there mitigation
Well and Network Modeling Study
History of field post plateau rates of 150k bopd.
Challenges being faced to maintain 150k bopd