{"id":19231,"date":"2022-06-28T08:00:37","date_gmt":"2022-06-28T00:00:37","guid":{"rendered":"http:\/\/learncmg.cn\/?p=19231"},"modified":"2022-06-28T08:00:37","modified_gmt":"2022-06-28T00:00:37","slug":"simulation-of-depleted-gas-reservoir-for-underground-gas-storage","status":"publish","type":"post","link":"http:\/\/learncmg.cn\/?p=19231","title":{"rendered":"147. \u67af\u7aed\u6c14\u85cf\u5730\u4e0b\u50a8\u6c14\u5e93\u6570\u503c\u6a21\u62df\u7814\u7a76"},"content":{"rendered":"
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SIMULATION OF DEPLETED GAS RESERVOIR FOR UNDERGROUND GAS STORAGE<\/a><\/h3>\n

ABSTRACT
\nFor a natural gas importing country, \u201ctake or pay\u201d approach creates problems since the demand for natural gas varies during the year and the excess amount of natural gas should be stored.<\/p>\n

In this study, an underground gas storage project is evaluated in a depleted gas Field M. After gathering all necessary reservoir, fluid, production and pressure data, the data were adapted to computer language, which was used in a commercial simulator software (IMEX) that is the CMG\u2019s (Computer Modelling Group) new generation adoptivesimulator, to reach the history matching.<\/p>\n

The history matching which consists of the 4 year of production of the gas reservoir is the first step of this study. The simulation program was able to accomplish a good history match with the given parameters of the reservoir.<\/p>\n

Using the history match as a base, five different scenarios were created and forecast the injection and withdrawal performance of the reservoir. These scenarios includes 5 newly drilled horizontal wells which were used in combinations with the existing wells.<\/p>\n

With a predetermined injection rate of 13 MMcf\/D was set for all the wells and among the 5 scenarios, 5 horizontal \u2013 6 vertical injectors & 5 horizontal - 6 vertical producers is the most successful in handling the gas inventory and the time it takes for a gas injection and production period. After the determination of the well configuration, the optimum injection rate for the entire field was obtained and found to be 130 MMcf\/D by running different injection rates for all wells and then for only horizontal wells different injection rates were applied with a constant injection rate of 130 MMcf\/d for vertical wells.<\/p>\n

Then it has been found that it is better to apply the 5 th scenario which includes 5 horizontal \u2013 6 vertical injectors & 5 horizontal - 6 vertical producers having an injection rate of 130 MMcf\/d for horizontal and vertical wells. Since within the 5 th scenario, changing the injection rate to 1.3 Bcf\/d and 13 Bcf\/d, did not effect and change the average reservoir pressure significantly, it is best to carry out the project with the optimum injection rate which is 130 MMcf\/d.<\/p>\n

The total gas produced untill 2012 is 394 BCF and the gas injected is 340 BCF where the maximum average reservoir pressure was recovered and set into a new value of 1881 psi by injection and cushion gas pressure as 1371 psi by withdrawal. If 5 th scenario is compared with the others, there is an increase in injection and production performance about 90%.<\/p>\n

Keywords: Underground Gas Storage, Depleted Gas Reservoir, History Matching and Simulator.<\/p>\n

<\/p>\n<\/div>\n<\/div><\/div><\/div><\/div><\/div>","protected":false},"excerpt":{"rendered":"

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