Enhanced Gas Recovery for Tight Gas Reservoirs with Multiple-Fractured Horizontal Wells in the Late Stages of Exploitation: A Case Study in Changling Gas Field

Bo Ning, Junjian Li, Taixian Zhong, Jianlin Guo, Yuyang Liu, Ninghai Fu, Kang Bie and Fankun Meng ()
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Bo Ning: School of Petroleum Engineering, China University of Petroleum (Beijing), Beijing 102249, China
Junjian Li: School of Petroleum Engineering, China University of Petroleum (Beijing), Beijing 102249, China
Taixian Zhong: Science and Technology Management Department, China National Petroleum Corporation (CNPC), Beijing 100007, China
Jianlin Guo: Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
Yuyang Liu: School of Petroleum Engineering, Yangtze University, Wuhan 430100, China
Ninghai Fu: Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
Kang Bie: Research Institute of Petroleum Exploration & Development, Tarim Oilfield Company, PetroChina, Korla 841000, China
Fankun Meng: School of Petroleum Engineering, Yangtze University, Wuhan 430100, China

Energies, 2023, vol. 16, issue 24, 1-16

Abstract: To initially improve the gas production rate and shorten the payback period for tight gas reservoirs, the multiple-fractured horizontal well (MFHW) model is always applied. However, in the late stages of exploitation, it is difficult to adopt reasonable measures for enhanced gas recovery (EGR), particular for continental sedimentary formation with multiple layers, and efficient strategies for EGR in this type of gas field have not yet been presented. Therefore, in this paper, a typical tight gas reservoir in the late stages of exploitation, the Denglouku gas reservoir in Changling gas field, in which MFHWs were utilized and contributed to the communication of the higher Denglouku formation (0.34 mol% CO 2 ) and lower Yingcheng formation (27 mol% CO 2 ) during hydraulic fracturing, is studied comprehensively. Firstly, alongside the seismic, logging, drilling and experimental data, 3D geological and numerical simulation models are developed. According to the differences in CO 2 mole fractions for different formations, the gas production rate of MFHWs produced from Denglouku formation is accurately calculated. Then, the well gas production rate (WGPR) and the well bottom-hole pressure (WBHP) history are matched with the calculated values, and thus the types of remaining gas are provided through the fine reservoir description. Finally, in a combination of gas recovery and economics, the optimal infill well type and the adjustment scheme are determined. The results show that there are three main categories of remaining gas, which are areal distribution, abundant points, and marginal dispersion, and the ratios of reaming gas reserve for these three types are 80.3%, 4.2%, and 15.5%, respectively. For the tight gas reservoir developed by MFHWs with parallel and zipper patterns, the best infilling well type is the vertical well. The combination of patching holes, sidetracking, infilling and boosting can obtain the highest gas recovery, while the scheme with patching holes and sidetracking has the best economic benefits. To balance the gas recovery and economics, the measurement of patching holes, sidetracking and infilling with vertical wells is utilized. In the final production period, compared with the basic schemes, the gas recovery can increase by 5.5%. The primary novelty of this paper lies in the determination of the optimal infilling well types and its presentation of a comprehensive adjustment workflow for EGR in tight gas reservoirs. The conclusions in this paper can provide some guidance for other similar tight gas reservoirs developed with MFHWs in the later period.

Keywords: tight gas reservoir; multiple fractured horizontal wells; enhance gas recovery; infilling wells; remaining gas; adjustment schemes (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2023
References: View complete reference list from CitEc
Citations: View citations in EconPapers (1)

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