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Gas portfolio development and the need to support Nigeria's Gas master plan is currently a high priority effort in government and international companies. Therefore, it is important to have a standardized approach for the development of the Gas Cap reservoirs. This guideline will provide a clear process to support the asset/study team in securing appropriate approvals from the government regulatory body (e.g. DPR) for the development of the gas cap resources. Gas categorization guideline is adopted as a classification system for the company's gas reservoirs to help demonstrate the timing of availability of gas cap production. The classification is driven by the time remaining to produce the economic ultimate recovery from the oil rims associated with the gas caps and processing plants/evacuation ullage availability. The objectives of the guideline are: To facilitate development planning and gas forecasting via a transparent picture on what the gas resources categories are. While existing fields mature, the development decisions regarding the oil rims become focused on ever reducing infill drilling targets. It is important to be aware how these decisions impact the availability of the gas cap production. The classification helps to provide clarity and transparency in this respect. This clarity aids to demonstrate the robustness of the Company's gas delivery promise.To help in defining standardized approach in getting approval for gas cap development from Department of Petroleum Resources (DPR). In defining this approach, a concise Gas cap release methodology is developed to guide asset and study teams in taking decisions on Gas cap development. A clear workflow was developed for Gas Cap Development and subjected to company's internal assurance process. Proper value assessment is done comparing the oil development and the company's gas requirement. Several sensitivities were carried out on the reservoir gas cap blowdown timing and the total reservoir NPV against the different GCBD timing (Figure1). Figure 1GCBD Optimal Timing Sensitivity
Gas portfolio development and the need to support Nigeria's Gas master plan is currently a high priority effort in government and international companies. Therefore, it is important to have a standardized approach for the development of the Gas Cap reservoirs. This guideline will provide a clear process to support the asset/study team in securing appropriate approvals from the government regulatory body (e.g. DPR) for the development of the gas cap resources. Gas categorization guideline is adopted as a classification system for the company's gas reservoirs to help demonstrate the timing of availability of gas cap production. The classification is driven by the time remaining to produce the economic ultimate recovery from the oil rims associated with the gas caps and processing plants/evacuation ullage availability. The objectives of the guideline are: To facilitate development planning and gas forecasting via a transparent picture on what the gas resources categories are. While existing fields mature, the development decisions regarding the oil rims become focused on ever reducing infill drilling targets. It is important to be aware how these decisions impact the availability of the gas cap production. The classification helps to provide clarity and transparency in this respect. This clarity aids to demonstrate the robustness of the Company's gas delivery promise.To help in defining standardized approach in getting approval for gas cap development from Department of Petroleum Resources (DPR). In defining this approach, a concise Gas cap release methodology is developed to guide asset and study teams in taking decisions on Gas cap development. A clear workflow was developed for Gas Cap Development and subjected to company's internal assurance process. Proper value assessment is done comparing the oil development and the company's gas requirement. Several sensitivities were carried out on the reservoir gas cap blowdown timing and the total reservoir NPV against the different GCBD timing (Figure1). Figure 1GCBD Optimal Timing Sensitivity
Reservoir compartmentalization, either structural, stratigraphic, or combination, is one of key parameters for accurately characterizing the hydrocarbons distribution in the subsurface and it is an important component for optimizing hydrocarbon recovery. In order to accurately characterize its compartmentalization, structural synthesis has been applied for generating a representative structural configuration of the complex and highly faulted reservoirs of the studied field. This paper demonstrates detail structural synthesis of a Cretaceous Middle-Eastern carbonate reservoir. The studied field exhibits multiple fault blocks with different fluid composition and contacts variation. Log analysis and test results from a number of wells suggested oil rim with significant gas cap and water leg. Exploiting the oil and gas in highly faulted reservoir possesses a major challenge hence the optimum strategy of development plan was created. Multi-tectonics history of the Arabia in the region is demonstrated by both folding and brittle deformation represented by fault system comprising en echelon faults and joint sets. The most dominant faults are N75W and N45W trending strike slip fault systems. Kinematic analysis, outcrop analogue, and nearby field analogue revealed that the two fault systems have been developed by different tectonic events. The N75W trending faults have been developed as tensile fracture shortly prior to folding when SHmax azimuth was approximately oriented 120o azimuth. The N45W trending faults have been developed at a later stage possible as splay faults by branching from the pre-existing N75W when the SHmax trend was oriented approximately 90°. The N45W fault arrays show partitioning of displacement between the various splays, with relatively abrupt changes in the displacement at branchlines. Long ‘single faults’ are frequently shown to be segmented into en-echelon arrays. This expression defines a model of fault growth by radial propagation and linkage from a single seed fault as indicated from geometrical and kinematic evidence. Antithetic N45W fault exhibit a downward decrease in displacement towards a tip line near the N75W master fault. This suggests that the N45W faults were initially developed as Riedel shears which then propagated and linked to the pre-existing N75W system as splay faults. This has occurred by a continuous counterclockwise rotation of the causative SHmax stress from Cretaceous to present. Quantification of the orientations, segmentation, and offset magnitudes provided a foundation for defining their implications for fluid charging, fluid flow, and pressure development within the reservoir. Thus several development scenarios were constructed in order to maintain the pressure and production rate, considering various combinations of horizontal producers and injectors, number of wells, well orientation, horizontal length, and depletion schemes.
This paper focuses on developing a substantial oil reservoir in South Sumatra, Indonesia, characterized by a large gas cap and a bottom water aquifer. The reservoir comprises thick, clean sandstone from the Miocene Talang Akar Formation, deposited in a transitional estuarine complex with good porosity and lateral continuity due to an accreted channel complex. Initial production was gas-dominated, leading to its classification as a non-potential reservoir with a recovery factor (RF) of up to 79%. The recent success in infill drilling has resulted in nearly 4000 BOPD from the N2 layer, revealing the ongoing potential for oil reserves. The shift from gas to oil production in the reservoir is an intriguing phenomenon. To understand this shift, static and dynamic data from the latest infill drilling, along with current saturation logs from existing wells, are evaluated. This comprehensive analysis forms the basis for constructing a reservoir model. The model is expected to describe the reservoir's conditions from its initial state to the current condition and assess the potential for incremental production. The comprehensive reservoir model estimates gas in place at 41 BSCF with an RF of 79%, based on cumulative production of 33 BSCF. The estimated oil in place is 11 MMSTB with the current RF at only 10%, from 1.1 MMSTB. The results of the recent study present opportunities for further development in the N2 layer using clustering infill drilling, workovers, and pressure maintenance to optimize oil production. This is estimated to have a potential additional oil production of 3.9 MMSTB, representing a ‘New Life’ for the N2 layer by shifting the paradigm from developing the gas reservoir to developing the oil reservoir. The evaluation of the N2 layer can change the paradigm for gas reservoirs with oil rims. While the common rule in the oil and gas industry is to produce oil first to optimize oil recovery, the case of the N2 layer challenges this norm. Despite the reservoir producing a large volume of gas, the oil potential remains high and can be developed by considering various reservoir parameters, as explained in this paper.
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