Numerical Investigation of Effects of Subsequent Parent-Well Injection on Interwell Fracturing Interference Using Reservoir-Geomechanics-Fracturing Modeling
- Xuyang Guo (China University of Petroleum, Beijing) | Kan Wu (Texas A&M University) | Cheng An (Texas A&M University) | Jizhou Tang (Texas A&M University) | John Killough (Texas A&M University)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- August 2019
- Document Type
- Journal Paper
- 1,884 - 1,902
- 2019.Society of Petroleum Engineers
- hydraulic fracture model, infill well, coupled flow and geomechanics, interwell interference, parent well injection
- 10 in the last 30 days
- 267 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 12.00|
|SPE Non-Member Price:||USD 35.00|
Because of interwell interference, the completion and production of infill wells in unconventional reservoirs often change established production profiles for parent wells and lead to infill-well production lower than expected. Parent-well injection has been used in some fields in an attempt to reduce interwell interference. However, mixed responses were received from these attempts, and few modeling studies have been presented to investigate the mechanisms of the mixed responses. This study investigates the effects of subsequent injection in parent wells with legacy production on interwell interference using a data set from Eagle Ford Shale. A numerical-modeling work flow is presented for the characterization of poroelastic behaviors of multiphase-fluid diffusivity and rock deformation using the finite-element method and multifracture propagation using the displacement discontinuity method. It solves for the spatial-temporal evolutions of pore pressure and in-situ stress because of parent-well production and injection and models the fracture propagation during infill-well completion on the basis of updated heterogeneous in-situ stresses. Thus, the approach obtains the interwell fracture network comprising parent-well fractures and fractures from infill-well completion and captures fracture hits, which are necessary for the analysis of the injection effectiveness. Numerical results indicate that subsequent injections in parent wells make infill-well fractures grow more transversely, denoting improved completion qualities of infill wells. Also, the required subsequent injection volume leading to transverse infill-well fractures is positively correlated with the volume of legacy production in parent wells. In addition to subsequent injection volume, locations of perforation clusters along the infill well are another key parameter affecting the associated interwell interference. Results show that it is easier to generate fracture hits after infill-well completion, when perforation-cluster locations along the infill wellbore are identical to those along parent wellbores. In contrast, certain infill-wellbore perforation-cluster locations different from those in parent wellbores guarantee transverse infill-well fractures and avoid fracture hits during/after infill-well completion. On the basis of the numerical results in this specific study, when infill-well perforation cluster locations are properly placed, the volume of parent-well subsequent injection should be at least 76.9% of the total depleted liquid volume during the legacy production of parent wells for subsequent injection to be effective in avoiding fracture hits. This value is on a case-by-case basis and should not be generalized. The contribution of this work lies in its analyses of the mixed performance by parent-well subsequent injection in the reduction of interwell interference using a reservoir-geomechanics/fracturing modeling work flow.
|File Size||2 MB||Number of Pages||19|
Abousleiman, Y., Cheng, A. D., Cui, L. et al. 1996. Mandel’s Problem Revisited. Geotechnique 46 (2): 187–195. https://doi.org/10.1680/geot.19188.8.131.52.
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.
Ajisafe, F. O., Solovyeva, I., Morales, A. et al. 2017. Impact of Well Spacing and Interference on Production Performance in Unconventional Reservoirs, Permian Basin. Presented at the Unconventional Resources Technology Conference, Austin, Texas, 24–26 July. URTeC-2690466-MS. https://doi.org/10.15530/URTEC-2017-2690466.
Bangerth, W., Hartmann, R., and Kanschat, G. 2007. Deal.II—A General-Purpose Object-Oriented Finite Element Library. ACM Trans on Math Software (TOMS) 33 (4), Article No. 24. https://doi.org/10.1145/1268776.1268779.
Berchenko, I. and Detournay, E. 1997. Deviation of Hydraulic Fractures Through Poroelastic Stress Changes Induced by Fluid Injection and Pumping. Int J Rock Mech Min Sci 34 (6): 1009–1019. https://doi.org/10.1016/S1365-1609(97)80010-X.
Biot, M. A. 1941. General Theory of Three-Dimensional Consolidation. J Appl Phys 12 (2): 155–164. https://doi.org/10.1063/1.712886.
Biot, M. A. and Willis, D. G. 1957. The Elastic Coefficients of the Theory of Consolidation. J Appl Mech 24: 594–601.
Bhardwaj, P., Hwang, J., Manchanda, R. et al. 2016. Injection Induced Fracture Propagation and Stress Reorientation in Waterflooded Reservoirs. Presented at SPE Annual Technical Conference and Exhibition, Dubai, UAE, 26–28 September. SPE-181883-MS. https://doi.org/10.2118/181883-MS.
Bommer, P. A. and Bayne, M. A. 2018. Active Well Defense in the Bakken: Case Study of a Ten-Well Frac Defense Project, McKenzie County, ND. Presented at SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 23–25 January. SPE-189860-MS. https://doi.org/10.2118/189860-MS.
Bommer, P., Bayne, M., Mayerhofer, M. et al. 2017. Re-Designing From Scratch and Defending Offset Wells: Case Study of a Six-Well Bakken Zipper Project, McKenzie County, ND. Presented at SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 24–26 January. SPE-184851-MS. https://doi.org/10.2118/184851-MS.
Bruno, M. S. and Nakagawa, F. M. 1991. Pore Pressure Influence on Tensile Fracture Propagation in Sedimentary Rock. Int J Rock Mech Min Sci Geomech Abst 28 (4): 261–273. https://doi.org/10.1016/0148-9062(91)90593-B.
Cao, R., Li, R., Girardi, A. et al. 2017. Well Interference and Optimum Well Spacing for Wolfcamp Development at Permian Basin. Presented at Unconventional Resources Technology Conference, Austin, Texas, 24–26 July. URTeC-2691962-MS. https://doi.org/10.15530/URTEC-2017-2691962.
Dean, R. H., Gai, X., Stone, C. M. et al. 2006. A Comparison of Techniques for Coupling Porous Flow and Geomechanics. SPE J. 11 (1): 132–140. SPE-79709-PA. https://doi.org/10.2118/79709-PA.
Elbel, J. L., Piggott, A. R., and Mack, M. G. 1992. Numerical Modeling of Multilayer Fracture Treatments. Presented at Permian Basin Oil and Gas Recovery Conference, Midland, Texas, 18–20 March. SPE-23982-MS. https://doi.org/10.2118/23982-MS.
Ferrill, D. A., McGinnis, R. N., Morris, A. P. et al. 2014. Control of Mechanical Stratigraphy on Bed-Restricted Jointing and Normal Faulting: Eagle Ford Formation, South-Central Texas. AAPG Bull 98 (11): 2477–2506. https://doi.org/10.1306/08191414053.
Gakhar, K., Rodionov, Y., Defeu, C. et al. 2017. Engineering an Effective Completion and Stimulation Strategy for In-Fill Wells. Presented at SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 24–26 January. SPE-184835-MS. https://doi.org/10.2118/184835-MS.
Geertsma, J. 1957. The Effect of Fluid Pressure Decline on Volumetric Changes of Porous Rocks. In Petroleum Transactions, AIME, Volume 210, 331–340, SPE-728-G. Richardson, Texas: Society of Petroleum Engineers.
Geertsma, J. 1966. Problems of Rock Mechanics in Petroleum Production Engineering. Presented at 1st ISRM Congress, Lisbon, Portugal, 25 September–1 October. ISRM-1CONGRESS-1966-099.
Guo, X., Wu, K., An, C. et al. 2019. Understanding the Mechanism of Interwell Fracturing Interference Based on Reservoir-Geomechanics-Fracturing Modeling in Eagle Ford Shale. SPE Res Eval & Eng. 22 (3): 842–860. SPE-194493-PA. https://doi.org/10.2118/194493-PA.
Guo, X., Wu, K., Killough, J. 2018. Investigation of Production-Induced Stress Changes for Infill Well Stimulation in Eagle Ford Shale. SPE J. 23 (4): 1372–1388. SPE-189974-PA. https://doi.org/10.2118/189974-PA.
Gupta, J., Zielonka, M., Albert, R. A. et al. 2012. Integrated Methodology for Optimizing Development of Unconventional Gas Resources. Presented at SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 6–8 February. SPE-152224-MS. https://doi.org/10.2118/152224-MS.
Hubbert, M. K. 1957. Darcy’s Law and the Field Equations of the Flow of Underground Fluids. International Association of Scientific Hydrology. Bulletin 2 (1): 23–59. https://doi.org/10.1080/02626665709493062.
Hughes, T. J. R. 1987. The Finite Element Method: Linear Static and Dynamic Finite Element Analysis. Englewood Cliffs, New Jersey: Prentice-Hall.
Hwang, J., Bryant, E. C., and Sharma, M. M. 2015. Stress Reorientation in Waterflooded Reservoirs. Presented at SPE Reservoir Simulation Symposium, Houston, Texas, 23–25 February. SPE-173220-MS. https://doi.org/10.2118/173220-MS.
King, G. E. and Valencia, R. L. 2016. Well Integrity for Fracturing and Re-Fracturing: What Is Needed and Why? Presented at SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 9–11 February. SPE-179120-MS. https://doi.org/10.2118/179120-MS.
King, G. E., Rainbolt, M.F., and Swanson, C. 2017. Frac Hit Induced Production Losses: Evaluating Root Causes, Damage Location, Possible Prevention Methods and Success of Remedial Treatments. Presented at SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 9–11 October. SPE-187192-MS. https://doi.org/10.2118/187192-MS.
Lindsay, G., Miller, G., Xu, T. et al. 2018. Production Performance of Infill Horizontal Wells vs. Pre-Existing Wells in the Major US Unconventional Basins. Presented at SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 23–25 January. SPE-189875-MS. https://doi.org/10.2118/189875-MS.
Mack, M. G., Elbel, J. L., and Piggott, A. R. 1992. Numerical Representation of Multilayer Hydraulic Fracturing. Presented at the 33th US Symposium on Rock Mechanics, Santa Fe, New Mexico, 3–5 June. ARMA-92-0335.
Mandel, J. 1953. Consolidation Des Sols (E´ tude Mathe´matique) [Consolidation of Solids (Mathematical Study)]. Geotechnique 3 (7): 287–299. https://doi.org/10.1680/geot.19184.108.40.2067.
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.
McNamee, J. and Gibson, R. E. 1960a. Displacement Functions and Linear Transforms Applied to Diffusion Through Porous Elastic Media. Q J Mech Appl Math 13 (1): 98–111. https://doi.org/10.1093/qjmam/13.1.98.
McNamee, J. and Gibson, R. E. 1960b. Plane Strain and Axially Symmetric Problems of the Consolidation of a Semi-Infinite Clay Stratum. Q J Mech Appl Math 13 (2): 210–217. https://doi.org/10.1093/qjmam/13.2.210.
Miller, G., Lindsay, G., Baihly, J. et al. 2016. Parent Well Refracturing: Economic Safety Nets in an Uneconomic Market. Presented at SPE Low Perm Symposium, Denver, Colorado, 5–6 May. SPE-180200-MS. https://doi.org/10.2118/180200-MS.
Olson, J. E. and Wu, K. 2012. Sequential Versus Simultaneous Multi-Zone Fracturing in Horizontal Wells: Insights From a Non-Planar, Multi-Frac Numerical Model. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 6–8 February. SPE-152602-MS. https://doi.org/10.2118/152602-MS.
Rainbolt, M. F. and Esco, J. 2018. Frac Hit Induced Production Losses: Evaluating Root Causes, Damage Location, Possible Prevention Methods and Success of Remediation Treatments, Part II. Presented at SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 23–25 January. SPE-189853-MS. https://doi.org/10.2118/189853-MS.
Roussel, N. P., Florez, H., and Rodriguez, A. A. 2013. Hydraulic Fracture Propagation From Infill Horizontal Wells. Presented at SPE Annual Technical Conference and Exhibition, New Orleans, Louisiana, 30 September–2 October. SPE-166503-MS. https://doi.org/10.2118/166503-MS.
Safari, R., Lewis, R., Ma, X. et al. 2017. Infill-Well Fracturing Optimization in Tightly Spaced Horizontal Wells. SPE J. 22 (2): 1–14. SPE-178513-PA. https://doi.org/10.2118/178513-PA.
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 50th US Rock Mechanics/Geomechanics Symposium, Houston, Texas, 26–29 June. ARMA-2016-190.
Singh, V., Roussel, N. P., and Sharma, M. M. 2008. Stress Reorientation and Fracture Treatments in Horizontal Wells. Presented at SPE Annual Technical Conference and Exhibition, Denver, Colorado, 21–24 September. SPE-116092-MS. https://doi.org/10.2118/116092-MS.
Siriwardane, H. J. and Layne, A. W. 1991. Improved Model for Predicting Multiple Hydraulic Fracture Propagation From a Horizontal Well. Presented at SPE Eastern Regional Meeting, Lexington, Kentucky, 22–25 October. SPE-23448-MS. https://doi.org/10.2118/23448-MS.
Terzaghi, K. 1923. Die Berechnung der Durchassigkeitsziffer des Tones aus Dem Verlauf der Hidrodynamichen Span-nungserscheinungen. Akad Wiss Wien Sitzungsber 11: 105–124.
Vincent, M. 2011. Restimulation of Unconventional Reservoirs: When Are Refracs Beneficial? J Can Pet Technol 50 (5): 36–52. SPE-136757-PA. https://doi.org/10.2118/136757-PA.
Wu, K. and Olson, J. E. 2015a. Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells. SPE J. 20 (2): 337–346. SPE-167626-PA. https://doi.org/10.2118/167626-PA.
Wu, K. and Olson, J. E. 2015b. A Simplified Three-Dimensional Displacement Discontinuity Method for Multiple Fracture Simulations. Int J Fract 193 (2): 191–204. https://doi.org/10.1007/s10704-015-0023-4.
Wu, R., Kresse, O., Weng, X. et al. 2012. Modeling of Interaction of Hydraulic Fractures in Complex Fracture Networks. Presented at SPE Hydraulic Fracture Technology Conference, The Woodlands, Texas, 6–8 February. SPE-152052-MS. https://doi.org/10.2118/152052-MS.
Yang, D., Moridis, G. J., and Blasingame, T. A. 2014. A Fully Coupled Multiphase Flow and Geomechanics Solver for Highly Heterogeneous Porous Media. J Comput Appl Math 270: 417–432. https://doi.org/10.1016/j.cam.2013.12.029.
Zoback, M. D. 2007. Reservoir Geomechanics. Cambridge, UK: Cambridge University Press. https://doi.org/10.1017/CBO9780511586477.