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Water injection is one of the most useful techniques for enhancing the production of oil from petroleum reservoirs. This is not only because of the low cost of water but also because of the characteristics of the water which help sweep the trapped oil efficiently. In this research, the main aim is to investigate how far a reservoir may produce oil...
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... seen from the results, the possible cumulative oil production for the first case study was only 9,350,662 STB out of the original oil in the reservoir which is 275,447,700 STB whereas the cumulative oil production at the end of the simulation process for the second case study was 85,383,000 STB as shown on Figure 8. This increase in the oil production played an important role in increasing the oil recovery factor from 3.4% for the first case study to 31% for the second case study out of the original oil in the reservoir as illustrated on Figure 9. With regard to the water production, the produced water from the first case study when there was no water injection was 21,470 STB as there had not been any additional water to enter the reservoir. ...
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... Once the injection fluid is prepared, it needs to be transferred/ injected from the tank to the borehole through concealed pipes (Cubillos et al. 2007;Hadi et al. 2016). While injecting the fluid into the borehole, injector and producer wellbore volumes are also considered (Davarpanah et al. 2019;Sallam et al. 2015). For example, to inject 50m 3 of injection fluid into a well whose wellbore volume is 10m 3 , an additional 20m 3 (10m 3 for injector well and 10m 3 for producer well) of push volume needs to be injected after injection of tracer fluid. ...
The significance of the tracer testing technique is widely accepted in reservoir performance analysis in hydrology as well as in hydrocarbon exploration and production. The subsurface reservoir delineation for hydrocarbon exploration and optimum production is one of the most critical aspects of petroleum system analysis. The quality of the reservoir and its performance prediction require extensive knowledge of qualitative reservoir geology, its depositional environment, facies heterogene-ity and engineering properties of subsurface formations. Tracer testing is amongst the few techniques available in the oil and gas (O&G) industry, which stands up to these expectations and is successfully used for quantitative determination and analysis of sub-seismic scale structural and stratigraphic heterogeneities. Tracer testing is also being utilized in determining residual oil saturation (S or) and lateral correlation of reservoir properties in the subsurface. Apart from the O&G industry, the concentration-based applications of tracer testing have been proved in hydrology, geothermal and medical science. A comprehensive review is presented to explain the application of tracer testing technique to investigate porous media, mainly in O&G industry. The type of tracers used, their selection criteria, concentration, and natural versus gradient and qualitative to a quantitative application are discussed in the current review. Generally, two types of tracers (chemical and radioactive) are preferred in the petroleum industry for gas/fluid flow assessment, waterflood optimization and establishing connectiv-ity between multiple wells. The current paper reviews both types of tracer tests, namely single well and inter well, in detail discussing the objectives, calculations, designing, injection, sampling, laboratory analysis and knowledge integration. The preliminary aim was to provide a review of the tracer testing technique used in reservoir evaluation and well-to-well con-nectivity analysis.
... This implies that if waterflooding was implemented right at the start of the field development, much oil would have been recovered (Tables 4 and 6). According to Sallam et al. [47] the implementation of waterflood increased oil production by 31% of the original oil in place. ...
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matured. Economically, production will not be profitable if the oil price goes below 46 US$/bbl.
Keywords: Field development; Reservoir; Matured oilfield; Waterflood simulation; Catshill
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Early water and gas breakthrough is a challenge for developing thin oil rim reservoirs. Secondary recovery methods suchas water, gas, simultaneous water and gas (SWAG) and gravity-assisted simultaneous water and gas injection (GASWAG)methods are proven methods for developing thin oil rim reservoirs. Knowledge about a preferred technique is important tominimize cost and enhance performance. In this study, various water and gas injection scenarios applied to thin oil rimreservoirs were evaluated using reservoir simulation studies such that horizontal and vertical wells were used for productionand injection respectively. The performance indicators considered include cumulative oil produced, oil production rate, andthe onset of water and gas coning. Simulation results showed that injecting gas at the gas-oil contact (case 1) and at thewater-oil contact (case 2) were the least favorable in improving oil recovery and in delaying gas coning and gas-cap surfaceproduction. SWAG and GASWAG resulted to an increase in production rate by 18.5% and 37.9% respectively incomparison to gas injection. Water injection at water-oil contact (case 3), SWAG and GASWAG augmented reservoirpressure with GASWAG sustaining the force balance within the reservoir much more than other methods during thesimulation period. GASWAG technique also resulted to a 28% increase in cumulative oil produced in comparison toSWAG. This is because the GASWAG technique improved sweep efficiency with the downward movement of water andthe upward movement of injected gas. Results from this study shows that GASWAG is a preferred method for developingthin oil rim reservoirs and should be adopted. It is however recommended to carry out an optimization study whichdetermines the optimal input parameters for a GASWAG process that maximizes cumulative oil produced and delays waterand gas breakthrough.
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