Effect of Pressure-Propagation Behavior on Production Performance: Implication for Advancing Low-Permeability Coalbed-Methane Recovery
- Zheng Sun (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing)) | Juntai Shi (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing)) | Keliu Wu (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing)) | Tao Zhang (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing)) | Dong Feng (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing)) | Xiangfang Li (MOE Key Laboratory of Petroleum Engineering and State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing))
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- April 2019
- Document Type
- Journal Paper
- 681 - 697
- 2019.Society of Petroleum Engineers
- Low-permeability CBM reservoirs, Pressure propagation behavior, Production strategy, Dynamic desorption area
- 10 in the last 30 days
- 245 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 12.00|
|SPE Non-Member Price:||USD 35.00|
Low-permeability coalbed-methane (CBM) reservoirs possess unique pressure-propagation behavior, which can be classified further as the expansion characteristics of the drainage area and the desorption area [i.e., a formation in which the pressure is lower than the initial formation pressure and critical-desorption pressure (CDP), respectively]. Inevitably, several fluid-flow mechanisms will coexist in realistic coal seams at a certain production time, which is closely related to dynamic pressure and saturation distribution. To the best of our knowledge, a production-prediction model for CBM wells considering pressure-propagation behavior is still lacking. The objective of this work is to perform extensive investigations into the effect of pressure-propagation behavior on the gas-production performance of CBM wells. First, the pressure-squared approach is used to describe the pressure profile in the desorption area, which has been clarified as an effective-approximation method. Also, the pressure/saturation relationship that was developed in our previous research is used; therefore, saturation distribution can be obtained. Second, an efficient iteration algorithm is established to predict gas-production performance by combining a new gas-phase-productivity equation and a material-balance equation. Finally, using the proposed prediction model, we shed light on the optimization method for production strategy regarding the entire production life of CBM wells. Results show that the decrease rate of bottomhole pressure (BHP) should be slow at the water single-phase-flow stage, fast at the early gas/water two-phase-flow stage, and slow at the late gas/water two-phase-flow stage, which is referred to as the slow/fast/slow (SFS) control method. Remarkably, in the SFS control method, the decrease rate of the BHP at each period can be quantified on the basis of the proposed prediction model. To examine the applicability of the proposed SFS method, it is applied to an actual CBM well in Hancheng Field, China, and it enhances the cumulative gas production by a factor of approximately 1.65.
|File Size||868 KB||Number of Pages||17|
Agarwal, A., Mandal, A., Karmakar, B. et al. 2013. Modeling and Performance Prediction for Water Production in CBM Wells of an Eastern India Coalfield. J. Petrol. Sci. Eng. 103: 115–120. https://doi.org/10.1016/j.petrol.2013.02.006.
Chen, Z. W., Liu, J. S., Kabir, A. et al. 2013. Impact of Various Parameters on the Production of Coalbed Methane. SPE J. 18 (5): 910–923. SPE-162722-PA. https://doi.org/10.2118/162722-PA.
Clarkson, C. R. and Qanbari, F. 2015. Transient Flow Analysis and Partial Water Relative Permeability Curve Derivation for Low-Permeability Undersaturated Coalbed Methane Wells. Int. J. Coal Geol. 152: 110–124. https://doi.org/10.1016/j.coal.2015.10.008.
Clarkson, C. R. and Qanbari, F. 2016. A Semi-Analytical Method for Forecasting Wells Completed in Low-Permeability, Undersaturated CBM Reservoirs. J. Nat. Gas Sci. Eng. 30: 19–27. https://doi.org/10.1016/j.jngse.2016.01.040.
Clarkson, C. R. and Salmachi, A. 2017. Rate-Transient Analysis of an Undersaturated CBM Reservoir in Australia: Accounting for Effective Permeability Changes Above and Below Desorption Pressure. J. Nat. Gas Sci. Eng. 40: 51–60. https://doi.org/10.1016/j.jngse.2017.01.030.
Dejam, M., Ghazanfari, M. H., Mashayekhizadeh, V. et al. 2011. Factors Affecting the Gravity Drainage Mechanism From a Single Matrix Block in Naturally Fractured Reservoirs. Special Topics & Reviews in Porous Media—An International Journal 2 (2): 115–124. https://doi.org/10.1615/10.1615/SpecialTopicsRevPorousMedia.v2.i2.50.
Dejam, M., Hassanzadeh, H., and Chen, Z. 2014a. Reinfiltration Through Liquid Bridges Formed Between Two Matrix Blocks in Fractured Rocks. J. Hydrol. 519: 3520–3530. https://doi.org/10.1016/j.jhydrol.2014.10.050.
Dejam, M., Hassanzadeh, H., and Chen, Z. 2014b. Shear Dispersion in a Fracture With Porous Walls. Adv. Water Resour. 74: 14–25. https://doi.org/10.1016/j.advwatres.2014.08.005.
Dejam, M., Hassanzadeh, H., and Chen, Z. 2017. Pre-Darcy Flow in Porous Media. Water Resour. Res. 53 (10): 8187–8210. https://doi.org/10.1002/2017WR021257.
Dejam, M. and Hassanzadeh, H. 2018. Diffusive Leakage of Brine From Aquifers During CO2, Geological Storage. Adv. Water Resour. 111: 36–57. https://doi.org/10.1016/j.advwatres.2017.10.029.
Duan, P., Wang, Z., Zhai, Y. et al. 2011. Research on Reasonable Depressurization Rate in Initial Stage of Exploitation to Coal Bed Methane. J. Chin. Coal. Soc. 36 (10): 1689–1692.
Feng, R., Harpalani, S., and Pandey, R. 2016. Laboratory Measurement of Stress-Dependent Coal Permeability Using Pulse-Decay Technique and Flow Modeling With Gas Depletion. Fuel 177: 76–86. https://doi.org/10.1016/j.fuel.2016.02.078.
Gentzis, T., Goodarzi, F., Cheung, F. K. et al. 2008. Coalbed Methane Producibility From the Mannville Coals in Alberta, Canada: A Comparison of Two Areas. Int. J. Coal Geol. 74 (3): 237–249. https://doi.org/10.1016/j.coal.2008.01.004.
Herckenrath, D., Doherty, J., and Panday, S. 2015. Incorporating the Effect of Gas in Modelling the Impact of CBM Extraction on Regional Groundwater Systems. J. Hydrol. 523 (1): 587–601. https://doi.org/10.1016/j.jhydrol.2015.02.012.
Ibrahim, A. F. and Nasr-El-Din, H. A. 2015. A Comprehensive Model to History Match and Predict Gas/Water Production From Coal Seams. Int. J. Coal Geol. 146: 79–90. https://doi.org/10.1016/j.coal.2015.05.004.
Jones, E. J. P., Harris, S. H., Barnhart, E. P. et al. 2013. The Effect of Coal Bed Dewatering and Partial Oxidation on Biogenic Methane Potential. Int. J. Coal Geol. 115 (8): 54–63. https://doi.org/10.1016/j.coal.2013.03.011.
Kucuk, F. and Brigham, W. E. 1979. Transient Flow in Elliptical Systems. SPE J. 19 (6): 401–410. SPE-7488-PA. https://doi.org/10.2118/7488-PA.
Lang, Z. 2011. Mechanics of Oil and Gas Flow in Porous Media. Dongying: Petroleum University Press.
Li, G. F. and Hou, Q. L. 2012. Dynamic Process and Difference of Coalbed Methane Wells Production in Southern Qinshui Basin. Journal of China Coal Society 37 (5): 798–803.
Li, S., Tang, D., Pan, Z. et al. 2013. Characterization of the Stress Sensitivity of Pores for Different Rank Coals by Nuclear Magnetic Resonance. Fuel 111 (3): 746–754. https://doi.org/10.1016/j.fuel.2013.05.003.
Li, J., Li, X., Shi, J. et al. 2017. Mechanism of Liquid-Phase Adsorption and Desorption in Coalbed Methane Systems: A New Insight Into an Old Problem. SPE Res Eval & Eng 20 (3): 639–653. SPE-177001-PA. https://doi.org/10.2118/177001-PA.
Liu, H., Sang, S., Formolo, M. et al. 2013. Production Characteristics and Drainage Optimization of Coalbed Methane Wells: A Case Study From Low-Permeability Anthracite Hosted Reservoirs in Southern Qinshui Basin, China. Energy Sustain. Dev. 17 (5): 412–423. https://doi.org/10.1016/j.esd.2013.04.005.
Mallick, N. and Prabu, V. 2017. Energy Analysis on Coalbed Methane (CBM) Coupled Power Systems. J. CO2 Util. 19: 16–27. https://doi.org/10.1016/j.jcou.2017.02.012.
Moridis, G. J., Reagan, M. T., Kuzma, H. A. et al. 2013. SeTES: A Self-Teaching Expert System for the Analysis, Design, and Prediction of Gas Production From Unconventional Gas Resources. Comput. Geosci. 58 (2): 100–115. https://doi.org/10.1016/j.cageo.2013.04.001.
Nie, R. S., Meng, Y. F., Guo, J. C. et al. 2012. Modeling Transient Flow Behavior of a Horizontal Well in a Coal Seam. Int. J. Coal Geol. 92 (2): 54–68. https://doi.org/10.1016/j.coal.2011.12.005.
Palmer, I. 2009. Permeability Changes in Coal: Analytical Modeling. Int. J. Coal Geol. 77 (1): 119–126. https://doi.org/10.1016/j.coal.2008.09.006.
Saurabh, S. and Harpalani, S. 2018. Stress Path With Depletion in Coalbed Methane Reservoirs and Stress-Based Permeability Modeling. Int. J. Coal Geol. 185: 12–22. https://doi.org/10.1016/j.coal.2017.11.005.
Seidle, J. P. 1993. Long-Term Gas Deliverability of a Dewatered Coalbed. J Pet Technol 45 (6): 564–569. SPE-21488-PA. https://doi.org/10.2118/21488-PA.
Shi, J., Wang, S., Zhang, H. et al. 2018. A Novel Method for Formation Evaluation of Undersaturated Coalbed Methane Reservoirs Using Dewatering Data. Fuel 229: 44–52. https://doi.org/10.1016/j.fuel.2018.04.144.
Spivey, J. P. and Semmelbeck, M. E. 1995. Forecasting Long-Term Gas Production of Dewatered Coal Seams and Fractured Gas Shales. Presented at the Low-Permeability Reservoirs Symposium, Denver, 19–22 March. SPE-29580-PA. https://doi.org/10.2118/29580-PA.
Sun, X., Zhang, Y., Li, K. et al. 2016. A New Mathematical Simulation Model for Gas Injection Enhanced Coalbed Methane Recovery. Fuel 183: 478–488. https://doi.org/10.1016/j.fuel.2016.06.082.
Sun, Z., Li, X., Shi, J. et al. 2017a. A Semi-Analytical Model for Drainage and Desorption Area Expansion During Coal-Bed Methane Production. Fuel 204: 214–226. https://doi.org/10.1016/j.fuel.2017.05.047.
Sun, Z., Li, X., Shi, J. et al. 2017b. Apparent Permeability Model for Real Gas Transport Through Shale Gas Reservoirs Considering Water Distribution Characteristic. Int. J. Heat Mass Tran. 115: 1008–1019. https://doi.org/10.1016/j.ijheatmasstransfer.2017.07.123.
Sun, Z., Li, X., Shi, J. et al. 2018a. A Semi-Analytical Model for the Relationship Between Pressure and Saturation in the CBM Reservoirs. J. Nat. Gas Sci. Eng. 49: 365–375. https://doi.org/10.1016/j.jngse.02017.11.022.
Sun, Z., Shi, J., Wang, K. et al. 2018b. The Gas-Water Two-Phase Flow Behavior in Low-Permeability CBM Reservoirs With Multiple Mechanisms Coupling. J. Nat. Gas Sci. Eng. 52: 82–93. https://doi.org/10.1016/j.jngse.2018.01.027.
Sun, Z., Shi, J., Zhang, T. et al. 2018c. A Fully-Coupled Semi-Analytical Model for Effective Gas/Water Phase Permeability During Coal-Bed Methane Production. Fuel 223: 44–52. https://doi.org/10.1016/j.fuel.2018.03.012.
Sun, Z., Shi, J., Zhang, T. et al. 2018d. The Modified Gas-Water Two-Phase Version Flowing Material-Balance Equation for Low-Permeability CBM Reservoirs. J. Petrol. Sci. Eng. 165: 726–735. https://doi.org/10.1016/j.petrol.2018.03.011.
Thararoop, P., Karpyn, Z. T., and Ertekin, T. 2015. A Production Type-Curve Solution for Coalbed Methane Reservoirs. J. Unconv. Oil Gas Resour. 9: 136–152. https://doi.org/10.1016/j.juogr.2014.12.001.
Vishal, V., Singh, L., Pradhan, S. P. et al. 2013. Numerical Modeling of Gondwana Coal Seams in India as Coalbed Methane Reservoirs Substituted for Carbon Dioxide Sequestration. Energy 49: 384–394. https://doi.org/10.1016/j.energy.2012.09.045.
Wan, Y., Liu, Y., Ouyang, W. et al. 2016. Desorption Area and Pressure-Drop Region of Wells in a Homogeneous Coalbed. J. Nat. Gas Sci. Eng. 28: 1–14. https://doi.org/10.1016/j.jngse.2015.11.026.
Wang, K., Li, H., Wang, J. et al. 2017. Predicting Production and Estimated Ultimate Recoveries for Shale Gas Wells: A New Methodology Approach. Appl. Energy 206: 1416–1431. https://doi.org/10.1016/j.apenergy.2017.09.119.
Wu, K., Chen, Z., Li, J. et al. 2017. Wettability Effect on Nanoconfined Water Flow. P. Natl. Acad. Sci. USA 114 (13): 3358–3363. https://doi.org/10.1073/pnas.1612608114.
Xu, B., Li, X., Haghighi, M. et al. 2013. An Analytical Model for Desorption Area in Coal-Bed Methane Production Wells. Fuel 106 (2): 766–772. https://doi.org/10.1016/j.fuel.2012.12.082.
Xu, H., Tang, D. Z., Tang, S. H. et al. 2014. A Dynamic Prediction Model for Gas–Water Effective Permeability on the Basis of Coalbed Methane Production Data. Int. J. Coal Geol. 121: 44–52. https://doi.org/10.1016/j.coal.2013.11.008.
Xu, B., Li, X., Ren, W. et al. 2017. Dewatering Rate Optimization for Coal-Bed Methane Well Based on the Characteristics of Pressure Propagation. Fuel 188: 11–18. https://doi.org/10.1016/j.fuel.2016.09.067.
Zhang, J. and Bian, X. 2015. Numerical Simulation of Hydraulic Fracturing Coalbed Methane Reservoir With Independent Fracture Grid. Fuel 143 (10): 543–546. https://doi.org/10.1016/j.fuel.2014.11.070.
Zhang, T., Li, X., Sun, Z. et al. 2017. An Analytical Model for Relative Permeability in Water-Wet Nanoporous Media. Chem. Eng. Sci. 174: 1–12. https://doi.org/10.1016/j.ces.2017.08.023.
Zhang, L., Kou, Z., Wang, H. et al. 2018. Performance Analysis for a Model of a Multi-Wing Hydraulically Fractured Vertical Well in a Coalbed Methane Gas Reservoir. J. Petrol. Sci. Eng. 166: 104–120. https://doi.org/10.1016/j.petrol.2018.03.038.
Zhao, J., Tang, D., Xu, H. et al. 2014. A Dynamic Prediction Model for Gas-Water Effective Permeability in Unsaturated Coalbed Methane Reservoirs on the Basis of Production Data. J. Nat. Gas Sci. Eng. 21: 496–506. https://doi.org/10.1016/j.jngse.2014.09.014.
Zhao, H. and Firoozabadi, A. 2017. Sorption Hysteresis of Light Hydrocarbons and Carbon Dioxide in Shale and Kerogen. Sci. Rep. 7 (1): 16209. https://doi.org/10.1038/s41598-017-13123-7.
Ziarani, A. S., Aguilera, R., and Clarkson, C. R. 2011. Investigating the Effect of Sorption Time on Coalbed Methane Recovery Through Numerical Simulation. Fuel 90 (7): 2428–2444. https://doi.org/10.1016/j.fuel.2011.03.018.
Zidane, A. and Firoozabadi, A. 2017. Fracture Cross-Flow Equilibrium in Compositional Two-Phase Reservoir Simulation. SPE J. 22 (3): 950–970. SPE-184402-PA. https://doi.org/10.2118/184402-PA.