CO2 EOR and Sequestration in a Depleted Gas-Condensate Reservoir: UKNS Case Study
- Obuekwe Mogbo (Imperial College)
- Document ID
- Society of Petroleum Engineers
- Nigeria Annual International Conference and Exhibition, 30 July - 3 August, Abuja, Nigeria
- Publication Date
- Document Type
- Conference Paper
- 2011. Society of Petroleum Engineers
- 5.5.8 History Matching, 4.6 Natural Gas, 5.2.2 Fluid Modeling, Equations of State, 5.7.2 Recovery Factors, 4.2 Pipelines, Flowlines and Risers, 5.2 Fluid Characterization, 5.7.5 Economic Evaluations, 5.4.3 Gas Cycling, 5.5.7 Streamline Simulation, 5.4 Enhanced Recovery, 5.2 Reservoir Fluid Dynamics, 4.1.4 Gas Processing, 4.1.5 Processing Equipment, 6.5.7 Climate Change, 5.5 Reservoir Simulation, 4.1.2 Separation and Treating, 5.4.9 Miscible Methods, 5.4.2 Gas Injection Methods, 4.3.4 Scale, 5.10.1 CO2 Capture and Sequestration, 5.2.1 Phase Behavior and PVT Measurements, 6.5.3 Waste Management, 5.7 Reserves Evaluation, 5.8.8 Gas-condensate reservoirs, 5.1.1 Exploration, Development, Structural Geology, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 2.2.2 Perforating
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This paper comprises a portion of a development study to investigate the applicability of CO2 for enhanced oil recovery and sequestration in a field in the central UKNS. The study focused on compositional simulations to predict the Minimum Miscibility Pressures, describe prognosed miscibility mechanisms and estimate incremental hydrocarbon recovery from full field simulations.
Depleted gas condensate fields are important targets for CO2 sequestration/EOR. Once depleted below the dew point, retrograde condensate is deposited in the pore system. CO2 injection in the depleted gas condensate reservoirs may allow enhanced gas recovery by liquid re-vaporization and reservoir re-pressurization or pressure maintenance. It is also noted that an accurate EOS fluid characterization is essential for CO2 miscible displacement, which is a composition-sensitive process. As such, compositional modelling is preferred.
For the phenomenological stage of the study, 1D slimtube compositional simulation models were used to estimate the Minimum miscibility pressure (MMP) of representative fluids in the Oil and depleted gas condensate legs. Different grid-block sizes were used to consider the effect of numerical dispersion on the MMP. Subsequently, ID finescale block compositional simulation models were used to study and verify the multi-contact miscibility mechanism existent in the depleted condensate legs.
The 3D full field model is highly compartmentalized with nine different panels having separate PVT characteristics. Each panel has a 12 component Peng-Robinson equation of state which is conditioned to its individual fluid. CO2 injection for repressurisation is simulated up to and beyond MMP, contact miscibility is attained and gas cycling is implemented for incremental oil recovery. After EOR, production ends and injection is continued for estimation of the maximum amount of CO2 to be sequestered. Furthermore, typical economic analysis for CO2 EOR project justification is done. The results enabled correct investment decision making by showing that CO2 EOR is technically but not economically justified for this field.
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