Integrated Well Interference Modeling Reveals Optimized Well Completion and Spacing in the Marcellus Shale
- Piyush Pankaj (Schlumberger) | Priyavrat Shukla (Schlumberger) | Payam Kavousi (West Virginia University) | Timothy Carr (West Virginia University)
- Document ID
- Society of Petroleum Engineers
- SPE Annual Technical Conference and Exhibition, 24-26 September, Dallas, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.8.2 Shale Gas, 5.8 Unconventional and Complex Reservoirs, 3 Production and Well Operations, 4 Facilities Design, Construction and Operation, 2.1 Completion Selection and Design, 5.8.6 Naturally Fractured Reservoir, 5.5 Reservoir Simulation, 5 Reservoir Desciption & Dynamics, 4.1.2 Separation and Treating, 2.1 Completion Selection and Design, 0.2 Wellbore Design, 3 Production and Well Operations, 5.1.5 Geologic Modeling, 3.3 Well & Reservoir Surveillance and Monitoring, 2.4 Hydraulic Fracturing, 5.5.8 History Matching, 0.2.2 Geomechanics, 2.5.2 Fracturing Materials (Fluids, Proppant), 3 Production and Well Operations, 3.3.6 Integrated Modeling, 2 Well completion, 4.1 Processing Systems and Design
- marcellus, Unconventional, Complex Fractures, shale gas, well spacing
- 6 in the last 30 days
- 307 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Naturally fractured reservoirs such as the Marcellus shale require an integrated reservoir modeling approach to determine well spacing and well-to-well interference. The Marcellus Shale Energy and Environment Laboratory (MSEEL) is a joint project between universities, companies, and government to develop and test new completion technologies and acquire a robust understanding of the Marcellus shale. The study presented in this paper aims to reveal an approach to determine reservoir depletion with time through coupled geological modeling and geomechanical evaluation followed by completion and well performance history matching for a multiwell pad in the Marcellus shale.
The geomechanical model was prepared with interpreted vertical log data. A discrete natural fracture (DFN) model was created and used to determine the complexity of hydraulic fracture geometry simulated through complex fracture models on a two well pad. The microseismic data obtained during the hydraulic fracture simulations served as a constraining parameter for the hydraulic fracture footprint in these wells. Sensitivity to the DFN is realized by parametric variations of DFN properties to achieve a calibrated fracture geometry. Reservoir simulation and history matching the well production data confirmed the subsurface production response to the hydraulic fractures. Well spacing sensitivity was done to reveal the optimum distance that the wells need to be spaced to maximize recovery and number of wells per section.
Hydraulic fracture geometry was found to be a result of the calibration parameters, such as horizontal stress anisotropy, fracturing fluid leakoff, and the DFN. The availability of microseismic data and production history matching through integrated numerical simulation are therefore critical elements to bring unique representation of the subsurface reaction to the injected fracturing fluid. This approach can therefore be consistently applied to evaluate well spacing and interference in time for the subsequent wells completed in the Marcellus. With the current completion design and pumping treatments, the optimal well spacing of 990 ft was determined between the wells in this study. However, wells to be completed in the future needs to be modeled due to the heterogeneity in the reservoir properties to ensure that wells are not either underspaced to cause well production interference or overspaced to create upswept hydrocarbon reserves in the formation.
By adopting the key learnings and approach followed in this paper, operators can maximize subsurface understanding and will be able to place their wellbore in a nongeometric pattern based on reservoir heterogeneity to optimize well spacing and improve recovery.
|File Size||3 MB||Number of Pages||16|
Carr, T. R., Wilson, T., Kavousi, P. 2017. Insights from the Marcellus Shale Energy and Environment Laboratory (MSEEL). Presented at the Unconventional Resources Technology Conference, Austin, Texas, USA, 24-26 July. URTEC-2670437-MS. https://doi.org/10.15530/URTEC-2017-2670437
Cipolla, C. L., Fitzpatrick, T., Williams, M. J., . 2011a. Seismic-to-Simulation for Unconventional Reservoir Development. Presented at the SPE Reservoir Characterisation and Simulation Conference and Exhibition, Abu Dhabi, UAE, 9-11 October. SPE-146876-MS. https://doi.org/10.2118/146876-MS
Cipolla, C. L., Weng, X., Mack, M. G.. 2011b. Integrating Microseismic Mapping and Complex Fracture Modeling to Characterize Hydraulic Fracture Complexity. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, USA, 24-26 January. SPE-140185-MS. https://doi.org/10.2118/140185-MS
EIA. 2016. Marcellus, Utica Provide 85% of U.S. Shale Gas Production Growth since Start of 2012. https://www.eia.gov/todayinenergy/detail.php?id=22252 (accessed 12 June 2018).
Ejofodomi, E., Baihly, J. D., Malpani, R.. 2011. Integrating All Available Data to Improve Production in the Marcellus Shale. Presented at the North American Unconventional Gas Conference and Exhibition, The Woodlands, Texas, USA, 14-16 June. https://doi.org/10.2118/144321-MS
Ghahfarokhi, P. K., Carr, T., Song, L.. 2018. Seismic Attributes Application for the Distributed Acoustic Sensing Data for the Marcellus Shale: New Insights to Cross-Stage Flow Communication. Presented at the SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, USA, 23–25 January. https://doi.org/10.2118/189888-MS
Ghahfarokhi, P. K., Carr, T., Song, L., Shukla, P., & Pankaj, P. (2018, January 23). Seismic Attributes Application for the Distributed Acoustic Sensing Data for the Marcellus Shale: New Insights to Cross-Stage Flow Communication. Society of Petroleum Engineers. doi: 10.2118/189888-MS
Liu, H., Luo, Y., Li, X.. 2012. Advanced Completion and Fracturing Techniques in Tight Oil Reservoirs in Ordos Basin: A Workflow to Maximum Well Potential. Presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 8–10 October. SPE-158268-MS. https://doi.org/10.2118/158268-MS
Marongiu-Porcu, M., Lee, D., Shan, D., & Morales, A. (2015, September 28). Advanced Modeling of Interwell Fracturing Interference: an Eagle Ford Shale Oil Study. Society of Petroleum Engineers. doi: 10.2118/174902-MS.
Pankaj, P., Geetan, S., MacDonald, R. (2015). Reservoir Modeling for Pad Optimization in the Context of Hydraulic Fracturing. Presented at the SPE Asia Pacific Unconventional Resources Conference and Exhibition, Brisbane, Australia, 9–11 November. https://doi.org/10.2118/176865-MS
Pankaj, P., Gakhar, K., and Lindsay, G. 2016. When to Refrac? Combination of Reservoir Geomechanics with Fracture Modeling and Reservoir Simulation Holds the Answer. Presented at the SPE Asia Pacific Oil & Gas Conference and Exhibition, Perth, Australia, 25-27 October. https://doi.org/10.2118/182161-MS
Weng, X. 2014. Modeling of Complex Hydraulic Fractures in Naturally Fractured Formation. Journal of Unconventional Oil and Gas Resources, 9:114-135. https://doi.org/10.1016/j.juogr.2014.07.001
Weng, X., Kresse, O., Cohen, C.-E.. 2011. Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation. SPE Prod & Oper 26 (4): 368–380. https://doi.org/10.2118/140253-PA
Wilson, T., Carr, T., Carney, B. J.. 2016. Microseismic and Model Stimulation of Natural Fracture Networks in the Marcellus Shale, West Virginia. SEG Technical Program Expanded Abstracts 2016: 3088-3092. https://doi.org/10.1190/segam2016-13866107.1
Wu, R., Kresse, O., Weng, X.. 2012, Modeling of Interaction of Hydraulic Fractures in Complex Fracture Networks. Presented at the SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, USA, 6–8 February. SPE-152052-MS. https://doi.org/10.2118/152052-MS.