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Hydrocarbon gas flooding is one of the most applied miscible EOR processes in the oil industry. The process becomes extremely challenging in heterogeneous carbonate reservoirs. An inverted four-spot hydrocarbon (HC) gas injection pilot has been under execution since 2016 to address these challenges, in a heterogeneous multi-layered Oolitic carbonate reservoir in West Kuwait. The pilot consisted of a pre-flush phase of water injection (2016-19) followed by a gas injection phase (2021-2022). This paper describes modelling and history matching of pre-flush waterflood phase and forecasting ahead of gas injection phase. The pre-flush waterflood was carried out sequentially into four target layers, injecting a range of pore volumes in each layer and gathering wealth of pilot data including Inter-Well Tracer Test (IWTT), PLT/ILT, time-lapse saturation logging, coring, and VIT to assess the impact of heterogeneity on the displacement process. Integrated review of the acquired dataset was conducted leading to better understanding of the reservoir performance. Model calibration was challenging as variable tracer arrival and concentration profiles indicated high heterogeneity. Detailed compositional simulation studies were undertaken on hybrid sector models of the pilot area created from full-field models, incorporating newly drilled well tops, reservoir properties and full-field fluxes. High-level experimental designs were conducted leading to dynamic sector models calibration, by identifying layer connectivity and baffle introduction as the main modelling gaps. The results showed baffles to vertical flow play a key role in reservoir and fluid flow performance. The knowledge gained from the pre-flush pilot data review and modelling were instrumental in forecasting the pilot gas injection performance. Activities undertaken to forecast the gas injection pilot performance include a two-pronged strategy of using calibrated hybrid sector model realizations and simple box models. The box-models captured range of gas injection phase outcomes on a simplified finer resolution of injector-producer models, testing gas injection strategy sensitivities without any dependency on history match quality, while the calibrated hybrid sector models offered pilot gas injection outcomes accounting for pilot area wells interaction and full-field streamline fluxes, testing gas injection programme robustness. The approach tremendously helped with the surveillance programme design of the pilot gas injection phase. Novel integrated modelling workflows, history matching techniques and forecasting approaches were used in this study of a complex heterogeneous multi-layered carbonate reservoir. Results of which assisted KOC to plan and successfully implement the pilot gas injection phase and formulate a robust surveillance programme to capture the effects of gas injection process. Further, it will help in designing a road map for commercial deployment of gas injection on a field scale.
Hydrocarbon gas flooding is one of the most applied miscible EOR processes in the oil industry. The process becomes extremely challenging in heterogeneous carbonate reservoirs. An inverted four-spot hydrocarbon (HC) gas injection pilot has been under execution since 2016 to address these challenges, in a heterogeneous multi-layered Oolitic carbonate reservoir in West Kuwait. The pilot consisted of a pre-flush phase of water injection (2016-19) followed by a gas injection phase (2021-2022). This paper describes modelling and history matching of pre-flush waterflood phase and forecasting ahead of gas injection phase. The pre-flush waterflood was carried out sequentially into four target layers, injecting a range of pore volumes in each layer and gathering wealth of pilot data including Inter-Well Tracer Test (IWTT), PLT/ILT, time-lapse saturation logging, coring, and VIT to assess the impact of heterogeneity on the displacement process. Integrated review of the acquired dataset was conducted leading to better understanding of the reservoir performance. Model calibration was challenging as variable tracer arrival and concentration profiles indicated high heterogeneity. Detailed compositional simulation studies were undertaken on hybrid sector models of the pilot area created from full-field models, incorporating newly drilled well tops, reservoir properties and full-field fluxes. High-level experimental designs were conducted leading to dynamic sector models calibration, by identifying layer connectivity and baffle introduction as the main modelling gaps. The results showed baffles to vertical flow play a key role in reservoir and fluid flow performance. The knowledge gained from the pre-flush pilot data review and modelling were instrumental in forecasting the pilot gas injection performance. Activities undertaken to forecast the gas injection pilot performance include a two-pronged strategy of using calibrated hybrid sector model realizations and simple box models. The box-models captured range of gas injection phase outcomes on a simplified finer resolution of injector-producer models, testing gas injection strategy sensitivities without any dependency on history match quality, while the calibrated hybrid sector models offered pilot gas injection outcomes accounting for pilot area wells interaction and full-field streamline fluxes, testing gas injection programme robustness. The approach tremendously helped with the surveillance programme design of the pilot gas injection phase. Novel integrated modelling workflows, history matching techniques and forecasting approaches were used in this study of a complex heterogeneous multi-layered carbonate reservoir. Results of which assisted KOC to plan and successfully implement the pilot gas injection phase and formulate a robust surveillance programme to capture the effects of gas injection process. Further, it will help in designing a road map for commercial deployment of gas injection on a field scale.
A hydrocarbon gas injection pilot was successfully conducted in a complex heterogeneous multilayered Oolitic carbonate reservoir in Kuwait. The pilot strived towards de-risking technical and commercial feasibility for field-scale deployment of miscible CO2-WAG EOR development. The pilot consisted of a pre-flush water-injection phase (2016-19) followed by a gas injection phase (2021-22). This paper describes modelling challenges of pre-flush waterflood & miscible HC gas injection phase and its implications for Full-field CO2 development. The injection phases were carried out sequentially in three target layers, injecting a range of pore volumes in each layer and gathering wealth of data including Inter-well tracer data, PLT/ILT, time-lapse saturation logging, coring, PTA and VIT to assess the impact of heterogeneity on the displacement process. Detailed compositional simulation studies were undertaken on sector models of the pilot area created from full-field models, incorporating new data & full-field fluxes. Model calibration was challenging as variable tracer arrival and concentration profiles indicated high heterogeneity. Experimental designs were conducted leading to sector models calibration, by identifying layer-connectivity and baffle introduction. Detailed integrated static and dynamic modeling of the pilot area were conducted using compositional simulation models, incorporating pre-flush water and gas injection data, history-matched to production, injection, GOR, water-cut, pressure, tracer production concentration and arrival time, ILT/PLT and time-lapse saturation logs. This detailed assessment revealed the impact of heterogeneity including horizontal baffles and barriers on the displacement process. The knowledge gained from pre-flush pilot data review and modelling were instrumental in forecasting the pilot gas injection performance. Activities undertaken to forecast the gas injection pilot performance include a two-pronged strategy of using calibrated hybrid sector model realizations and simple box models. For the gas injection phase, calibration and improvement in history-match of the hybrid dynamic model was achieved by updating relative permeability end-points and baffles adjustment to match the observed gas tracer results. An integrated analysis of the gathered data, reservoir modeling & Residence Time Distribution analysis of water and gas tracers was conducted, providing an insight on reservoir de-saturation, inflow and sweep for the pre-flush and gas injection phases along with the achieved oil gain, assisting better understanding of the implications for future CO2 Water Alternating Gas (WAG) Enhanced Oil Recovery (EOR) full-field development. Novel integrated workflow consisting of robust surveillance techniques, reservoir modelling workflows along with tracer analysis techniques were used in this complex heterogeneous multi-layered carbonate reservoir study in understanding pore scale and reservoir scale sweep efficiency and its impact on oil recovery. The excellent result from the gas injection performance in pilot and surrounding wells has provided KOC an opportunity in designing a road map for full-field deployment of CO2 WAG in this world class field.
Reservoir model-based uncertainty analysis (UA) has been widely applied in the oil industry for decades, but it is still facing some challenges, e.g., integration and visualization of multi-dimensional (4D++) categorical and continuous input parameters. Workarounds, simplifications, or neglect have been utilized for tentative solutions. This paper presents a novel approach/workflow in the aim of attacking these challenges in reservoir model UA. Experimental design improvement for UA is not the focus of this paper. The proposed workflow was successfully applied to Kashagan, a giant carbonate oil field in Caspian Sea that consists of a matrix dominated platform and a non-matrix (NM) dominated rim. Despite 7 years of production/injection history, a wide range of uncertainties exist in reservoir characterization. To understand and mitigate their impact on field performance the subsurface uncertainties, a UA study was conducted. Categorical parameters (subsurface structure, fracture/karst distributions/connectivity, rock quality regions, reservoir heterogeneity etc.) and continuous parameters (matrix/non-matrix compressibility, dual-porosity/dual-permeability coupling parameter, aquifer size/connectivity, permeability/porosity, Kv/Kh ratio etc.) were used to characterize the subsurface uncertainties. Dynamic responses within 60-year forecast (oil/gas/water production/injection rates/ratios/cumulatives, recovery factor, oil in place, elapsed time, and objective function for field total/regions) were selected for analysis. Around 1000 simulation models were designed using standard DoE methods. Statistical analysis was conducted to identify linearity/non-linearity effects, correlations between input parameters, their statistical significances, and possible inflations during regression analysis. Multidimensional scaling was used to visualize the complex input-response relationship, QC&QA the responses and identify behaviors/characters (e.g., clusters) inside of the uncertainty space, which is not apparent in the original space. It opens a window into what the uncertainty scape is like and significantly improves the robustness of P10-P50-P90 (low, mid and high) models’ selection.
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