Construction of a 3D Geomechanical Model for Development of a Shale Gas Reservoir in Sichuan Basin
- Jun Xie (PetroChina) | Kaibin Qiu (Schlumberger) | Bing Zhong (PetroChina) | Yuanwei Pan (Schlumberger) | Xuewen Shi (PetroChina) | Lizhi Wang (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Russian Petroleum Technology Conference, 16-18 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Petroleum Engineers
- 5 Reservoir Desciption & Dynamics, 0.2.2 Geomechanics, 1.6 Drilling Operations, 5.8 Unconventional and Complex Reservoirs, 1.12 Drilling Measurement, Data Acquisition and Automation, 3 Production and Well Operations, 2.4 Hydraulic Fracturing, 5.8.2 Shale Gas, 1.12.3 Mud logging / Surface Measurements, 5.1.5 Geologic Modeling, 0.2 Wellbore Design, 2 Well completion, 2.5.2 Fracturing Materials (Fluids, Proppant)
- 7 in the last 30 days
- 219 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Currently, there is large-scale shale gas exploration and development in the Sichuan basin, western China. Due to high tectonic stress and presence of fracture systems at various scales in the lower Silurian Longmaxi reservoir formation, hydraulic fracturing in shale gas reservoirs in the Sichuan basin has encountered many difficulties, such as difficulty in placing sufficient proppant, poor production performance for some wells, and ambiguity as to the factors controlling production of the reservoir. It has been recognized that lack of geomechanical understanding of the shale gas reservoirs places a major obstacle to effectively addressing these difficulties.
A 3D full field geomechanics model was constructed for Changning shale gas reservoir in Sichuan basin through integrating seismic, geological structure, log, and core data by following a newly formulated integrated workflow. The 3D geomechanical model includes 3D anisotropic mechanical properties, 3D pore pressure, and the 3D in-situ stress field. Through leveraging measurements from an advanced sonic tool and core data, the anisotropy of the formation was captured at wellbores and propagated to 3D space guided by prestack seismic inversion data. 3D pore pressure prediction was conducted using seismic data and calibrated against pressure measurements, mud logging data, and flowback data. A discrete fracture network model, which represents multiscale natural fracture systems, was integrated into the 3D geomechanical model during stress modeling to reflect the disturbance on the in-situ stress field by the presence of the natural fracture systems.
The 3D pore pressure model was used to calculate more-reliable estimates of gas in place in the shale gas reservoir, and the geomechanical model was used to reveal the root cause of difficulties of proppant placement in this tectonically active and unevenly fractured shale gas reservoir.
The paper presents the highlights and innovations in constructing the 3D geomechanical model for the shale gas reservoir and explains how the 3D geomechanical model is used to understand the root cause of poor proppant placement encountered during hydraulic fracturing and events such as mud losses during drilling. Hence, the modeling provides a critical opportunity to improve reservoir stimulation in the shale gas reservoir.
|File Size||4 MB||Number of Pages||27|
Abousleiman Y., Tran M., Hoang S.. 2007. Geomechanics Field and Laboratory Characterization of the Woodford Shale: The Next Gas Play. Presented at the SPE Annual Technical Conference and Exhibition, Anaheim, California, USA, 11-14 November. SPE-110120-MS. https://doi.org/10.2118/110120-MS.
Alberty, M. W. and Fink, K. 2014. The Use of Connection and Total Gases Quantitatively in the Assessment of Shale Pore Pressure. SPE Drill & Completion 29 (2): 208-214. SPE-166188-PA. https://doi.org/10.2118/166188-PA.
Barton, N.R. 1972. A Model Study of Rock-Joint Deformation: Int. J. Rock Mech. Min. Sci. 9: 579-582. https://doi.org/10.1016/0148-9062(72)90010-1.
Bowers, G.L. 1995. Pore Pressure Estimation from Velocity Data: Accounting for Overpressure Mechanisms Besides Undercompaction. SPE Drill & Compl, 10 (2), 89-95. Paper SPE 27488-PA. doi: 10.2118/27488-PA.
Chen, M.Z., Qian, B., Ou, Z.L., 2012. Exploration and Practice of Volume Fracturing in Shale Gas Reservoir of Sichuan Basin, China. Presented at IADC/SPE Asia Pacific Conference & Exhibition, Tianjin, China, 9-11 July. SPE-155598-MS. https://doi.org/10.2118/155598-MS.
Eaton, B.A. 1975. The Equation for Geopressure Prediction from Well Logs. J Pet Technol 24 (8), 929-934. SPE-3719-PA. https://doi.org/10.2118/3719-PA.
Foster, J.B. and Whalen, J.E., 1966. Estimation of Formation Pressure from Electrical Surveys-Offshore Louisiana. J. Pet. Technol. 18 (2): 165—171. SPE-1200-PA. https://doi.org/10.2118/1200-PA.
Gale, J. F.W. 2014. Natural Fracture Patterns and Attributes Across a Range of Scales. AAPG Search and Discovery Article #41487. http://www.searchanddiscovery.com/pdfz/documents/2014/41486gale/ndx_gale.pdf.html (accessed 8 July 2017).
Hoesni, H.M. 2004. Origins of overpressure in the Malay Basin and its infuence on petroleum systems. Durham theses, Durham University. Available at Durham E-Theses Online: http://etheses.dur.ac.uk/1755/
Johnston J.E. and Christensen N.I. 1995. Seismic Anisotropy of Shales. Journal of Geophysical Research B 100: 5991-6003. https://doi.org/10.1029/95jb00031.
Jones R S, Pownall B, and Franke J. 2014. Estimating Reservoir Pressure from Early Flowback Data. Presented at the Unconventional Resources Technology Conference, Denver, Colorado, USA, 25-27 August. URTEC-1934785-MS. https://doi.org/10.15530/URTEC-2014-1934785.
Li, Q., Chen, M., Jin, Y.. 2013. Rock Mechanical Properties of Shale Gas Reservoir and Their Influences on Hydraulic Fracture. Paper Presented at the International Petroleum Conference, Beijing, China, 26-28 March. IPTC-16580-MS. https://doi.org/10.2523/IPTC-16580-MS.
Maerten, L., Gillespie, P., and Daniel, J.-M. 2006. Three-Dimensional Geomechanical Modeling for Constraint of Subseismic Fault Simulation. AAPG Bulletin 90 (9): 1337-1358. https://doi.org/10.1306/03130605148.
Pepper, R. and Bejarano, G. 2005. Advances in Seismic Fault Interpretation Automation. Search and Discovery Article #40169. http://www.searchanddiscovery.com/pdfz/documents/2005/pepper/images/pepper.pdf.html (accessed 7 July 2017).
Qiu, K.Cheng, N., Ke, X., Liu, Y.. 2013. 3D Reservoir Geomechanics Workflow and Its Application to a Tight Gas Reservoir in Western China. Paper IPTC 17115 Presented at the International Petroleum Technology Conference, Beijing, China, 26-28 March. IPTC-17115-MS. https://doi.org/10.2523/IPTC-17115-MS.
Randen, T., Pedersen, S.I., Sonneland, L. 2001. Automatic Extraction of Fault Surfaces from Three-Dimensional Seismic Data. Presented at SEG Technical Program Expanded Abstracts 2001: 551-554. https://doi.org/10.1190/1.1816675.
Suarez-Rivera, R., Deenadayalu, C., and Yang, Y.-K. 2009. Unlocking the Unconventional Oil and Gas Reservoirs: The Effect of Laminated Heterogeneity in Wellbore Stability and Completion of Tight Shale Gas Reservoirs. Presented at the Offshore Technology Conference, Houston, Texas, USA, 4-7 May. OTC-20269-MS. https://doi.org/10.4043/20269-MS.
Thiercelin, M.J. and Plumb, R.A. 1994. A Core-Based Prediction of Lithologic Stress Contrasts in East Texas Formations. SPE Form Eval 9 (4): 251-258. SPE-21847-PA. https://doi.org/10.2118/21847-PA.
Thomsen, L. 1986. Weak Elastic Anisotropy. Geophysics 51: 1954-1966. https://doi.org/10.1190/1.1442051.
Vernik, L. and Liu, X. 1997. Velocity Anisotropy in Shales: A Petrophysical Study. Geophysics 62: 521-532. https://doi.org/10.1190/1.1444162.
Wang, Z. 2002. Seismic Anisotropy in Sedimentary Rocks: Part 2 -Laboratory Data. Geophysics 67: 1423-1440. https://doi.org/10.1190/1.1512743.
Weng, X., Kresse, O., Cohen, C.. 2011. Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation. SPE Prod & Oper 26 (4): 368-380. SPE-140253-PA. http://dx.doi.org/10.2118/140253-PA.