Methodology and Field Application: Multiple Scale Propped Fractures to Maximize ESRV in Deep Buried Shale Gas Play With High Tectonic Stress in Sichuan Basin, China
- T. X. Jiang (Sinopec Research Institute of Petroleum Engineering) | Y. J. Zeng (Sinopec Research Institute of Petroleum Engineering) | Jian Zhou (Sinopec Research Institute of Petroleum Engineering) | X. B. Bian (Sinopec Research Institute of Petroleum Engineering) | Boheng Shen (Missouri University of Science and Technology) | H. T. Wang (Sinopec Research Institute of Petroleum Engineering) | Lei. Hou (Sinopec Research Institute of Petroleum Engineering) | Bo Xiao (Sinopec Research Institute of Petroleum Engineering)
- Document ID
- American Rock Mechanics Association
- 52nd U.S. Rock Mechanics/Geomechanics Symposium, 17-20 June, Seattle, Washington
- Publication Date
- Document Type
- Conference Paper
- 2018. American Rock Mechanics Association
- 1 in the last 30 days
- 59 since 2007
- Show more detail
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ABSTRACT: There are tremendous shale gas resources with depth of beyond 3500m in Sichuan basin, China. The tectonic stress is very high which causes an abnormally in-situ stress in this case, so that it brings challenges during horizontal staged fracturing, such as high breakdown pressure, low fracture complexity, low proppant concentration and weight, as well as less sufficient effective stimulated reservoir volume (ESRV) as expected. The research in this paper can improve the above situation. For achieving a better production in the shale formation, a new method of hydraulic fracturing technique was developed, including optimized perforation simulation, engineering solution for multiple scale fractures opening, the optimized propped method of multiple scale fractures, fracture height controlling. The simulation results demonstrated that the improving of fracture length, width and height is impressive which is 36%, 19% and 20%, respectively, after adopting 6 perforations in fixed plane perforation compared with 20 perforations in spiral perforation. In addition, the breakdown pressure was found to have an impressive decline after simulation by varied fluid viscosity from 200 mPa. s to 2.5 mPa. s. After adopting a combination of above work, the optimized design method has been applied in two wells for shale gas exploration.
1. BACK GROUND
The deep shale gas resource was tremendous in China (Chen zuo et al., 2016), only in some districts located in Sichuan basin, it was estimated that there was about 4612×108m3 shale gas resource (Dong Dazhong et al., 2012) with buried depth more than 3500 m. Compared with that in shallow or middle depth of shale gas wells, the characteristics of geology and hydraulic fracturing are listed as following (Dehua zhou et al., 2014; Haitao Wang et al., 2016).
- The pumping rate is low due to higher in-situ stress and initiation pressure, so that the fracture width and the corresponding proppant concentration are all limited.
- Due to high differential stress between maximum horizontal stress minimum, the hydraulic fracture tend to be single fracture instead of network fractures. Meanwhile, the overburden pressure is maximal in most cases which may cause un-open of horizontal bedding fissures.
- Rock ductility is increased due to higher temperature and pore pressure in matrix, which may cause difficulties in fracture initiation and propagation.
- The conductivity within multiple scale fractures are all decreased quickly due to the higher in-situ stress magnitude. In this case, the higher stress magnitude and the larger crash ratio and embedment of proppant caused the reduction of fracture conductivity. In some extreme cases, the above mentioned conductivity may even decrease to near zero so that the ESRV is also accordingly decreased largely in this circumstance.
- In many cases, high angle natural fractures may exist with horizontal bedding fissures synchronously, especially in the south of the structure in many shale gas blocks, so that the initiation and propagation mechanisms of hydraulic fractures are very complicated and poor understood. In this case, if the pumping rate and the viscosity of fracturing fluid are not adaptable, the fracture height may be out of control, and the ESRV may not be available as expected.
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