Browsing by Subject "waterflood"
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Item Advances in the development and application of a capacitance-resistance model(2013-05) Laochamroonvorap, Rapheephan; Lake, Larry W.Much effort of reservoir engineers is devoted to the time-consuming process of history matching in a simulator to understand the reservoir complexity. Its accuracy is debatable because only a few inputs are known. Several analytical tools have been developed to investigate reservoir heterogeneity. The reciprocal productivity index (RPI) is a tool to measure the pressure support observed at a producer. The log (water-oil ratio or WOR) plot can be used to indicate the presence of a channel. A capacitance-resistance model (CRM) is a simple tool to estimate the connectivity between a producer-injector pair from the production/injection and pressure data. Generally field operators implement an improved recovery plan such as water-alternating-gas (WAG) flood to improve displacement efficiency. However, the existence of heterogeneity compromises its performance. The first objective of this study is to improve the assessment of tertiary flood performance by integrating the CRM with other analytical tools. The integrated method was applied to a miscible flood field in West Texas. The results suggest strong interwell connectivity found more frequently in the NE-SW direction and the different preferential flow paths of injected CO2 and water. Overall, the results provide insights into the current flood status. The operating conditions of a producer dynamically change because of well/field constraints. These changes can induce significant interference in other wells, which cannot be captured by CRM. The second objective of this study is to develop a capacitance-resistance model with producer-producer interaction (CRMP-P). The CRMP-P, derived from the continuity and Darcy’s equations, accounts for producer-producer interactions. The CRMP-P was applied to data from three different reservoir models. The results suggest that the CRMP-P could fit the data with higher precision than CRM. Consequently, the CRMP-P estimates of reservoir properties are more accurate. Moreover, the estimated transmissibility between producers is in agreement with the reservoir models. The CRMP-P was also applied to Omani field data. The transmissibility results are consistent with previous study and the drilling information. The more accurate information on producer-producer interactions and reservoir properties can assist in history-matching, locating infill wells, and reservoir management planning.Item Reservoir Characterization and Waterflood Performance Evaluation of Granite Wash Formation, Anadarko Basin(2014-05-08) Nilangekar, Akshay AnandThe Granite wash formation in the Anadarko basin is classified as a tight-gas play and is located along the Texas ? Oklahoma border. It has a complex mineralogy and consists of stacked-pay series of tight sands. Our zone of interest is the liquid-rich Missourian Wash B interval in Wheeler County in which two horizontal wells have been drilled. The purpose of this research is to characterize the reservoir through geologic modeling and determine the feasibility of a waterflood using simulation studies. A set of field data was provided by the operator and other necessary parameters were obtained through publicly available field studies and literature. The final objective is implementing advanced reservoir simulation to integrate well log data, PVT data, diagnostic fracture injection test and microseismic analysis into a plan of development. The Missourian Wash B formation has a maximum net pay thickness of 50ft. The target sand is laterally continuous which makes it an ideal horizontal drilling prospect. The wells are stimulated by multi-stage hydraulic fracturing. The initial production gas-oil ratio is 1800 scf/stb and PVT reports indicate presence of an oil reservoir above bubble point pressure. PVT correlations show that the 42? API oil and potential injection water at the reservoir temperature have almost the same viscosity. All these factors point towards the formation being a good waterflood candidate. Well log analysis was performed to obtain porosity and saturation estimates. The microseismic mapping report provides a good overview of the well completion efficiency. Laboratory PVT data was tuned to predict reservoir fluid behavior by parameter regression and component lumping. An isotropic black-oil simulator by Computer Modeling Group Ltd was selected for our work. The reservoir model was validated by sensitivity studies and history matching of production rates was performed. Simulation result of waterflood implementation by utilizing offset horizontal wells as injectors is analyzed, and three different plans of development are discussed. It is seen that the overall response to waterflooding is poor due to low formation permeability leading to low water injectivity. But a greater reservoir area can be drained if production is initiated from additional horizontal wells. A well-spacing of four horizontal wells in 600 acres section is recommended. The stimulated reservoir volumes of adjacent wells should be close to each other for effective reservoir drainage.