A Numerical Model for Simulating Pressure Response of Well Interference and Well Performance in Tight Oil Reservoirs With Complex-Fracture Geometries Using the Fast Embedded-Discrete-Fracture-Model Method
- Wei Yu (Texas A&M University) | Yifei Xu (University of Texas at Austin) | Ruud Weijermars (Texas A&M University) | Kan Wu (Texas A&M University) | Kamy Sepehrnoori (University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- May 2018
- Document Type
- Journal Paper
- 489 - 502
- 2018.Society of Petroleum Engineers
- Hydraulic fracture hits, Shale oil, Natural fractures, Well interference, Complex fracture geometries
- 6 in the last 30 days
- 587 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 12.00|
|SPE Non-Member Price:||USD 35.00|
The effect of well interference through fracture hits in shale reservoirs needs to be investigated because hydraulic fracturing is abundantly used in the development of unconventional oil and gas resources. Although numerous pressure tests have proved the existence of well interference, relatively few physical models exist to quantitatively simulate the pressure response of well interference. The objective of the present study is to develop a numerical compositional model in combination with a fast embedded-discrete-fracture-model (EDFM) method to simulate well interference. Through nonneighboring connections (NNCs), the fast EDFM method can easily and properly handle complex-fracture geometries, such as nonplanar hydraulic fractures and a large amount of natural fractures. Using public data for Eagle Ford tight oil, we build a reservoir model including up to three horizontal wells and five fluid pseudocomponents. The simulation results show that the connecting hydraulic fractures play a more-important role than natural fractures in declining bottomhole pressure (BHP) of the shut-in well. Matrix permeability has a relatively minor effect on pressure drawdown, and well productivity remains only slightly affected by the overall low permeability used. The BHP pressure-decline profiles change from convex to concave when the conductivity of the connecting fractures increases. At early times, the BHP of the shut-in well decreases when the number of natural fractures increases. At later times, the natural-fracture density has a lesser effect on the pressure response and no clear trend. The opening order of neighboring wells affects the well-interference intensity between the target shut-in well and the surrounding wells. After a systematic investigation of pressure drawdown in the reservoir, we formulate practical conclusions for improved production performance.
|File Size||2 MB||Number of Pages||14|
Ajani, A. A. and Kelkar, M. G. 2012. Interference Study in Shale Plays. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 6–8 February. SPE-151045-MS. https://doi.org/10.2118/151045-MS.
Awada, A., Santo, M., Lougheed, D. et al. 2016. Is That Interference? A Work Flow for Identifying and Analyzing Communication through Hydraulic Fractures in a Multi-Well Pad. SPE J. 21 (5): 1554–1566. SPE-178509-PA. https://doi.org/10.2118/178509-PA.
Cipolla, C. and Wallace, J. 2014. Stimulated Reservoir Volume: A Misapplied Concept? Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 4–6 February. SPE-168596-MS. https://doi.org/10.2118/168596-MS.
Computer Modelling Group (CMG). 2012. GEM User’s Guide. Calgary: CMG.
de Araujo Cavalcante Filho, J. S., Shakiba, M., Moinfar, A. et al. 2015. Implementation of a Preprocessor for Embedded Discrete Fracture Modeling in an IMPEC Compositional Reservoir Simulator. Presented at the SPE Reservoir Simulation Symposium, Houston, 23–25 February. SPE-173289-MS. https://doi.org/10.2118/173289-MS.
King, G. E. and Valencia, R. L. 2016. Well Integrity for Fracturing and Re-Fracturing: What is Needed and Why? Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 9–11 February. SPE-179120-MS. https://doi.org/10.2118/179120-MS.
Kurtoglu, B. and Salman, A. 2015. How to Utilize Hydraulic Fracture Interference to Improve Unconventional Development. Presented at the Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. SPE-177953-MS. https://doi.org/10.2118/177953-MS.
Lake, L. W. 1989. Enhanced Oil Recovery. Englewood Cliffs, New Jersey: Prentice Hall.
Lawal, H., Jackson, G., Abolo, N. et al. 2013. A Novel Approach to Modeling and Forecasting Frac Hits in Shale Gas Wells. Presented at the EAGE Annual Conference & Exhibition, London, 10–13 June. SPE-164898-MS. https://doi.org/10.2118/164898-MS.
Lindner, P. and Bello, H. 2015. Eagle Ford Well Spacing: A Methodology to Integrate, Analyze, and Visualize Multisource Data in Solving a Complex Value-Focused Problem. Presented at the Unconventional Resources Technology Conference, San Antonio, Texas, 20–22 July. URTEC-2174709-MS. https://doi.org/10.15530/URTEC-2015-2174709.
Lohrenz, J., Bray, B. G., and Clark, C. R. 1964. Calculating Viscosities of Reservoir Fluids from Their Compositions. J Pet Technol 16 (10): 1171–1176. SPE-915-PA. https://doi.org/10.2118/915-PA.
Malpani, R., Sinha, S., Charry, L. et al. 2015. Improving Hydrocarbon Recovery of Horizontal Shale Wells through Refracturing. Presented at the SPE/CSUR Unconventional Resources Conference, Calgary, 20–22 October. SPE-175920-MS. https://doi.org/10.2118/175920-MS.
Marongiu-Porcu, M., Lee, D., Shan, D. et al. 2016. Advanced Modeling of Interwell-Fracturing Interference: An Eagle Ford Shale-Oil Study. SPE J. 21 (5): 1567–1582. SPE-174902-PA. https://doi.org/10.2118/174902-PA.
Mehra, R. K., Heidemann, R. A., and Aziz, K. 1983. An Accelerated Successive Substitution Algorithm. Can. J. Chem. Eng. 61 (4): 590–596. https://doi.org/10.1002/cjce.5450610414.
Moinfar, A., Varavei, A., Sepehrnoori, K. et al. 2014. Development of an Efficient Embedded Discrete Fracture Model for 3D Compositional Reservoir Simulation in Fractured Reservoirs. SPE J. 19 (2): 289–303. SPE-154246-PA. https://doi.org/10.2118/154246-PA.
Orangi, A., Nagarajan, N. R., Honarpour, M. M. et al. 2011. Unconventional Shale Oil and Gas-Condensate Reservoir Production, Impact of Rock, Fluid, and Hydraulic Fractures. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 24–26 January. SPE-140536-MS. https://doi.org/10.2118/140536-MS.
Peaceman, D. W. 1978. Interpretation of Well-Block Pressures in Numerical Reservoir Simulation. SPE J. 18 (3): 183–194. SPE-6893. https://doi.org/10.2118/6893-PA.
Peng, D.-Y. and Robinson, D. B. 1976. A New Two-Constant Equation of State. Ind. Eng. Chem. Fundamen. 15 (1): 59–64. https://doi.org/10.1021/i160057a011.
Perschke, D. R., Chang, Y., Pope, G. A. et al. 1989. Comparison of Phase Behavior Algorithms For An Equation-Of-State Compositional Simulator. SPE-19443-MS.
Portis, D. H., Bello, H., Murray, M. et al. 2013. Searching for the Optimal Well Spacing in the Eagle Ford Shale: A Practical Tool-Kit. Presented at the Unconventional Resources Technology Conference, Denver, 12–14 August. URTEC-1581750-MS.
Sani, A. M., Podhoretz, S. B., and Chambers, B. D. 2015. The Use of Completion Diagnostics in Haynesville Shale Horizontal Wells to Monitor Fracture Propagation, Well Communication, and Production Impact. Presented at the SPE/CSUR Unconventional Resources Conference, Calgary, 20–22 October. SPE-175917-MS. https://doi.org/10.2118/175917-MS.
Sardinha, C. M., Petr, C., Lehmann, J. et al. 2014. Determining Interwell Connectivity and Reservoir Complexity through Frac Pressure Hits and Production Interference Analysis. Presented at the SPE/CSUR Unconventional Resources Conference, Calgary, 30 September–2 October. SPE-171628-MS. https://doi.org/10.2118/171628-MS.
Scott, K. D., Chu, W.-C., and Flumerfelt, R. W. 2015. Application of Real-Time Bottom-Hole Pressure to Improve Field Development Strategies in the Midland Basin Wolfcamp Shale. Presented at the Unconventional Resources Technology Conference, San Antonio, Texas, 20–22 July. URTEC-2154675-MS. https://doi.org/10.15530/URTEC-2015-2154675.
Shakiba, M. and Sepehrnoori, K. 2015. Using Embedded Discrete Fracture Model (EDFM) and Microseismic Monitoring Data to Characterize the Complex Hydraulic Fracture Networks. Presented at the SPE Annual Technical Conference and Exhibition, Houston, 28–30 September. SPE-175142-MS. https://doi.org/10.2118/175142-MS.
Simpson, M. D., Patterson, R., and Wu, K. 2016. Study of Stress Shadow Effects in Eagle Ford Shale: Insight from Field Data Analysis. Presented at the 50th US Rock Mechanics/Geomechanics Symposium, Houston, 26–29 June. ARMA-2016-190.
Wu, K. and Olson, J. E. 2016. Numerical Investigation of Complex Hydraulic-Fracture Development in Naturally Fractured Reservoirs. SPE Prod & Oper 31 (4): 300–309. SPE-173326-PA. https://doi.org/10.2118/173326-PA.
Wu, R., Kresse, O., Weng, X. et al. 2012. Modeling of Interaction of Hydraulic Fractures in Complex Fracture Networks. Presented at the SPE Hydraulic Fracture Technology Conference, The Woodlands, Texas, 6–8 February. SPE-152052-MS. https://doi.org/10.2118/152052-MS.
Xu, Y., Cavalcante Filho, J. S. A., Yu, W. et al. 2017. Discrete-Fracture Modeling of Complex Hydraulic-Fracture Geometries in Reservoir Simulators. SPE Res Eval & Eng 20 (2): 403–422. SPE-183647-PA. https://doi.org/10.2118/183647-PA.
Yaich, E., Diaz de Souza, O. C., Foster, R. A. et al. 2014. A Methodology to Quantify the Impact of Well Interference and Optimize Well Spacing in the Marcellus Shale. Presented at SPE/CSUR Unconventional Resources Conference, Calgary, 30 September–2 October. SPE-171578-MS. https://doi.org/10.2118/171578-MS.
Yu, W., Sepehrnoori, K., and Patzek, T. W. 2016. Modeling Gas Adsorption in Marcellus Shale with Langmuir and BET Isotherms. SPE J. 21 (2): 589–600. SPE-170801-PA. https://doi.org/10.2118/170801-PA.
Yu, W., Wu, K., Zuo, L. et al. 2016. Physical Models for Inter-Well Interference in Shale Reservoirs: Relative Impacts of Fracture Hits and Matrix Permeability. Presented at the Unconventional Resources Technology Conference, San Antonio, Texas, 1–3 August. URTEC-2457663-MS. https://doi.org/10.15530/URTEC-2016-2457663.
Zuloaga-Molero, P., Yu, W., Xu, Y. et al. 2016. Simulation Study of CO2-EOR in Tight Oil Reservoirs with Complex Fracture Geometries. Sci. Rep. 6: 33445. https://doi.org/10.1038%2Fsrep33445.