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The evaluation of the recoverable hydrocarbon volume and further development opportunities in complex reservoirs (where two or more reservoirs are hydraulically connected) primary challenges the engineer faces in managing such reservoirs. In this study, multi-tank material balance models have been built to solve these problems. The key criteria for a robust material balance modelling of hydraulically connected reservoirs in a single system are: (i) transmissibility across the reservoirs should be properly defined. Transmissibility is a major modelling component in achieving sound multi-tank MBAL models. It is useful to the estimation of the rate of aquifer movement across the reservoirs. (ii) Good understanding of the geology and production data of the reservoirs is helpful in estimating the appropriate transmissibility. (iii) Sufficient and quality Carbon-Oxygen logs, BHP and production data. CO logs are very important for proper calibration of hydrocarbon contact. Accurate BHP data is critical in the establishment of dynamic communication and matching of simulated versus measured reservoir pressure. In this paper two cases with over 30 years of production history are discussed in detail including the full methodology and the associated results. The results from these studies show good and reliable outcome which has provided the basis for the reported hydrocarbon resource volumes of the reservoirs (B1.0X, B1.0N, C1.0X, E9.0X, E10.0X, E11.0X, G1.0X, H1.0X) Results were compared with other methodologies (existing simulation models and DCA of NFA wells) and indicate good comparisons. The number of development opportunities in the 8 reservoirs were optimised from 22 to 20 wells using the multi-tank material balance model. Despite some known limitations of material balance generally, multi tank material balance model has proven to be a simple and reliable methodology in evaluating complex reservoir system with hydraulic communication. Especially, in situations where time and budget constraints will not support full field reservoir simulation modelling.
The evaluation of the recoverable hydrocarbon volume and further development opportunities in complex reservoirs (where two or more reservoirs are hydraulically connected) primary challenges the engineer faces in managing such reservoirs. In this study, multi-tank material balance models have been built to solve these problems. The key criteria for a robust material balance modelling of hydraulically connected reservoirs in a single system are: (i) transmissibility across the reservoirs should be properly defined. Transmissibility is a major modelling component in achieving sound multi-tank MBAL models. It is useful to the estimation of the rate of aquifer movement across the reservoirs. (ii) Good understanding of the geology and production data of the reservoirs is helpful in estimating the appropriate transmissibility. (iii) Sufficient and quality Carbon-Oxygen logs, BHP and production data. CO logs are very important for proper calibration of hydrocarbon contact. Accurate BHP data is critical in the establishment of dynamic communication and matching of simulated versus measured reservoir pressure. In this paper two cases with over 30 years of production history are discussed in detail including the full methodology and the associated results. The results from these studies show good and reliable outcome which has provided the basis for the reported hydrocarbon resource volumes of the reservoirs (B1.0X, B1.0N, C1.0X, E9.0X, E10.0X, E11.0X, G1.0X, H1.0X) Results were compared with other methodologies (existing simulation models and DCA of NFA wells) and indicate good comparisons. The number of development opportunities in the 8 reservoirs were optimised from 22 to 20 wells using the multi-tank material balance model. Despite some known limitations of material balance generally, multi tank material balance model has proven to be a simple and reliable methodology in evaluating complex reservoir system with hydraulic communication. Especially, in situations where time and budget constraints will not support full field reservoir simulation modelling.
The authors have used this paper to demonstrate how material balance was applied in field development planning for a green gas field. In this work, we have used one of the reservoirs as case study. Deterministic tank model was initially built for the reservoir using MBAL™. Petrophysical properties, aquifer parameters and relative permeability data were all added into the model. Well flow models were generated using PROSPER™ and then imported into MBAL™. Facility constraints were imposed, and deterministic prediction run was performed. Key impacting parameters on the recovery factor were assessed, and corresponding ranges were estimated for each. A probabilistic prediction workflow was developed and applied to the deterministic model. This uses experimental design to generate multiple runs with the aid of OpenServer™. Response/proxy function for gas recovery was then generated and tested for consistency with "observed" data. Multiple Monte Carlo runs were then done using Crystal ball, and the 10th, 50th and 90th percentiles were extracted. The corresponding parameters for these respective percentiles were then tested in MBAL™ to check for reliability. Finally, all reservoirs were rolled-up using GAP™, and the recovery factors were checked for consistency with MBAL™. The recovery factors (P10, P50 and P90) from the probabilistic material balance work were then compared with results from grid-based simulation work done on the reservoir. The figures were further compared with estimates from local and global analogues, as well as analysis done by a third-party. Results from the MBAL™ work compared reasonably with recovery factors from the other methods. Probabilistic material balance approach helps to remove bias/anchoring while estimating a range of outcomes for recovery factor. It also gives reasonable estimates, as demonstrated by the closeness of results with other methods. However, it is not a replacement especially for the grid-based simulation, but should rather be a complement. The methodology has been successfully applied to other gas fields and reliable results were also obtained. The work was equally adapted to more complex systems as multi-tank models.
Two methods exist for the estimation of Gas Initially In-Place – volumetrics (probabilistic or deterministic) and performance (material balance equation or numerical simulation). The more appropriate method will depend on the maturity of the project reservoir. For potential accumulations with limited information, the GIIP estimate may be volumetric-based using probabilistic methods, covering the range of possible outcomes with P90, P50 and P10 outcomes as low, best and high estimates. For fields where more subsurface data are available, the preferred method will generally shift towards volumetric-based GIIP estimates using deterministic low, best and high cases. Once a field is in production and sufficient data are available, a performance-based GIIP estimate should be established, including the appropriate range of uncertainty. Over the years, the tendency has been to over-rely on volumetric-based estimates with little attention paid to performance based GIIP update leading to sub-optimal gas field development. In this paper, we took a case-study reservoir having or tending towards negative reserves in course of its production life to underscore the need for timely update of GIIP based on performance data as an aid to optimal development of a gas field. Reservoir A has volumetrically based GIIP of 1.6 Tscf respectively leading to prediction of early End of Life (EOL) or negative reserves. When compared with performance based GIIP and updated volumetric GIIP of 2.04 Tscf to match performance data, the issue of early EOL or negative reserves was ameliorated and ultimate recoveries were optimized. Performance based GIIP estimate is reliable when premised on appropriate choice of methods (P/Z material balance for depletion reservoirs, aquifer influx model in water drive gas reservoirs material balance model or dynamic simulation) integrating all available data as illustrated in the case studies. To allow comparison between volumetric-based (static) and performance-based (dynamic) GIIP estimates and to understand the potential difference between the two, it is recommended that a current volumetric GIIP estimate should be maintained throughout the life of the field in addition to an up-to-date performance-based GIIP estimate to aid optimal gas field development.
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