Treatment of Rate-Transient Analysis During Boundary-Dominated Flow
- Hamid Behmanesh (Anderson Thompson Reservoir Strategies and University of Calgary) | Louis Mattar (IHS Global Canada) | John M. Thompson (Anderson Thompson Reservoir Strategies) | David M. Anderson (Anderson Thompson Reservoir Strategies) | Daniel W. Nakaska (Kappa Engineering) | Christopher R. Clarkson (University of Calgary)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- August 2018
- Document Type
- Journal Paper
- 1,145 - 1,165
- 2018.Society of Petroleum Engineers
- analytical model, Rate Transient Analysis, flowing material balance, multi-phase flow, boundary-dominated flow
- 26 in the last 30 days
- 630 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
Significant advances have been made in the development of analytical models for performing rate-transient analysis (RTA) for single-phase oil and gas reservoirs. The primary complication associated with the adaptation of these solutions to wells exhibiting multiphase flow is the single-phase assumption in the development of the material-balance time function. Despite some efforts in modifying existing dry-gas formulations for use with gas/condensate reservoirs, that approach is not practical for analyzing multiphase flow from oil wells with multiphase-flow characteristics.
In this work, we present a simple yet semianalytical model that provides a solution for analyzing production data from wells exhibiting multiphase flow during boundary-dominated flow periods. The solution is obtained by combining the material-balance equation and the productivity index (PI) for all flowing phases. Appropriately defined total pseudopressure and total pseudotime are introduced to handle the associated multiphase nonlinearities in the governing flow equations of oil, gas, and water phases simultaneously. A generalized flowing-material-balance (FMB) equation is derived from the total pseudovariables to estimate original fluid in place and drainage area (given volumetric input). The presented model provides a theoretical framework for analyzing production data considering a wide variety of reservoir-fluid systems.
The new method is validated against numerical simulation, covering a wide range of fluid properties and operating conditions. In all simulated cases, the new method matches simulation input acceptably. Two field examples are also analyzed to demonstrate the practical applicability of this approach. This work serves as a practical and simple engineering tool for production-data analysis on wells exhibiting single and multiphase flow during boundary-dominated flow.
|File Size||948 KB||Number of Pages||21|
Afidick, D., Kaczorowski, N. J., and Bette, S. 1994 Production Performance of a Retrograde Gas Reservoir: A Case Study of Arun Field. Presented at the SPE Asia Pacific Oil & Gas Conference, Melbourne, Australia, 7–10 November. SPE-28749-MS. https://doi.org/10.2118/28749-MS.
Agarwal, R. G. 1979. “Real Gas Pseudo-Time”—A New Function for Pressure Buildup Analysis of MHF Gas Wells. Presented at the SPE Annual Technical Conference and Exhibition, Las Vegas, Nevada, 23–26 September. SPE-8279-MS. https://doi.org/10.2118/8279-MS.
Agarwal, R. G., Gardner, D. C., Kleinsteiber, S. W. et al. 1999. Analyzing Well Production Data Using Combined-Type-Curve and Decline-Curve Analysis Concepts. SPE Res Eval & Eng 2 (5): 478–486. SPE-57916-PA. https://doi.org/10.2118/57916-PA.
Ayyalasomayajula, P., Silpngarmlers, N., and Kamath, J. 2005. Well Deliverability Predictions for a Low Permeability Gas Condensate Reservoir. Presented at the SPE Annual Technical Conference and Exhibition, Dallas, 9–12 October. SPE-95529-MS. https://doi.org/10.2118/95529-MS.
Behmanesh, H. 2016. Rate-Transient Analysis of Tight Gas Condensate and Black Oil Wells Exhibiting Two-Phase Flow. PhD dissertation, University of Calgary, Calgary.
Behmanesh, H., Hamdi, H., and Clarkson, C. R. 2015. Production Data Analysis of Tight Gas Condensate Reservoirs. J. Nat. Gas Sci. Eng. 22 (January): 22–34. https://doi.org/10.1016/j.jngse.2014.11.005.
Behmanesh, H., Hamdi, H., and Clarkson, C.R. 2017. Production Data Analysis of Gas Condensate Reservoirs Using Two-Phase Viscosity and Two-Phase Compressibility. J. Nat. Gas Sci. Eng. 47 (November): 47–58. https://doi.org/10.1016/j.jngse.2017.07.035.
Blasingame, T. A. and Lee, W. J. 1986. Variable-Rate Reservoir Limits Testing. Presented at the Permian Basin Oil and Gas Recovery Conference, Midland, Texas, 13–14 March. SPE-15028-MS. https://doi.org/10.2118/15028-MS.
Blasingame, T. A. and Lee, W. J. 1988. The Variable-Rate Reservoir Limits Testing of Gas Wells. Presented at the SPE Gas Technology Symposium, Dallas, 13–15 June. SPE-17708-MS. https://doi.org/10.2118/17708-MS.
Blasingame, T. A. and Rushing, J. A. 2005. A Production-Based Method for Direct Estimation of Gas in Place and Reserves. Presented at the SPE Eastern Regional Meeting, Morgantown, West Virginia, 14–16 September. SPE-98042-MS. https://doi.org/10.2118/98042-MS.
Camacho-V., R. G. and Raghavan, R. 1989. Performance of Wells in Solution-Gas-Drive Reservoirs. SPE Form Eval 4 (4): 611–620. SPE-16745-PA. https://doi.org/10.2118/16745-PA.
Clarkson, C. R., Behmanesh, H., and Chorney, L. 2013. Production-Data and Pressure-Transient Analysis of Horseshoe Canyon Coalbed-Methane Wells, Part II: Accounting for Dynamic Skin. J Can Pet Technol 52 (1): 41–53. SPE-148994-PA. https://doi.org/10.2118/148994-PA.
Coats, K. H. 1985. Simulation of Gas Condensate Reservoir Performance. J Pet Technol 37 (10): 1870–1886. SPE-10512-PA. https://doi.org/10.2118/10512-PA.
Corey, A. T. 1954. The Interrelation Between Gas and Oil Relative Permeabilities. Prod. Mon. 19: 38–41.
Danesh, A., Khazam, M., Henderson, G. D. et al. 1994. Gas Condensate Recovery Studies. Oral presentation given at the UK Department of Trade and Industry Improved Oil Recovery and Research Dissemination Seminar, London, June.
Evinger, H. H. and Muskat, M. 1942. Calculation of Theoretical Productivity Factor. Trans. AIME 146 (1): 126–139. SPE-942126-G. https://doi.org/10.2118/942126-G.
Fan, L., Harris, B., Jamaluddin, A. et al. 2005. Understanding Gas/Condensate Reservoirs. Oilfield Rev., Winter 2005/2006: 14–27.
Fevang, Ø. and Whitson, C. H. 1996. Modeling Gas/Condensate Well Deliverability. SPE Res Eng 11 (4): 221–230. SPE-30714-PA. https://doi.org/10.2118/30714-PA.
Fraim, M. L. 1987. Gas Reservoir Decline-Curve Analysis Using Type Curves With Real Gas Pseudopressure and Normalized Time. SPE Form Eval 2 (4): 671–682. SPE-14238-PA. https://doi.org/10.2118/14238-PA.
Jones, J. R., Vo, D. T., and Raghavan, R. 1989. Interpretation of Pressure-Buildup Responses in Gas/Condensate Wells. SPE Form Eval 4 (1): 93–104. SPE-15535-PA. https://doi.org/10.2118/15535-PA.
Mattar, L. and Anderson, D. 2006. Dynamic Material Balance-Oil-or Gas-in-Place Without Shut-Ins. J Can Pet Technol 45 (11): 7–10. PETSOC-06-11-TN. https://doi.org/10.2118/06-11-TN.
Mattar, L., Rushing, J. A., and Anderson, D. M. 2006. Production Data Analysis—Challenges, Pitfalls, Diagnostics. Presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 24–27 September. SPE-102048-MS. https://doi.org/10.2118/102048-MS.
Muskat, M. 1949. Physical Principles of Oil Production. New York City: McGraw-Hill.
Muskat, M. and Meres, M. 1936. The Flow of Heterogeneous Fluids Through Porous Media. Physics 7 (9): 346–363. https://doi.org/10.1063/1.1745403.
Nobakht, M. and Mattar, L. 2009. Diagnostics of Data Quality for Analysis of Production Data. Presented at the Canadian International Petroleum Conference, Calgary, 16–18 June. PETSOC-2009-137. https://doi.org/10.2118/2009-137.
O’Dell, H. G. and Miller, R. N. 1967. Successfully Cycling a Low-Permeability, High-Yield Gas Condensate Reservoir. J Pet Technol 19 (1): 41–47. SPE-1495-PA. https://doi.org/10.2118/1495-PA.
Palacio, J. C. and Blasingame, T. A. 1993. Decline Curve Analysis Using Type Curves Analysis of Gas Well Production Data. Oral presentation given at the Joint Rocky Mountain Regional and Low Permeability Reservoirs Symposium, Denver, 26–28 April.
Peñuela-Pineda, G. 1999. Prediction of the Gas-Condensate Well Productivity and Field Implementation Using a Compositional Model. Master’s thesis, University of Oklahoma, Norman, Oklahoma.
Ramey, H. J. Jr. 1971. Reservoir Engineering in the 70’s and 80’s. J Pet Technol 23 (1): 33–37. SPE-3273-PA. https://doi.org/10.2118/3273-PA.
Shahamat, M. S. and Clarkson, C. R. 2017. Multi-Well, Multi-Phase Flowing Material Balance. Presented at the SPE Unconventional Resources Conference, Calgary, 15–16 February. SPE-185052-MS. https://doi.org/10.2118/185052-MS.
Stalgorova, E. and Mattar, L. 2016. Analytical Methods for Single-Phase Oil Flow: Accounting for Changing Liquid and Rock Properties. Presented at the SPE Europec featured at 78th EAGE Conference and Exhibition, Vienna, Austria, 30 May–2 June. SPE-180139-MS. https://doi.org/10.2118/180139-MS.
Stewart, G. 2012. Wireline Formation Testing and Well Deliverability. Tulsa: PennWell.
Sureshjani, M. H. and Gerami, S. 2011. A New Model for Modern Production-Decline Analysis of Gas/Condensate Reservoirs. J Can Pet Technol 50 (7): 14–23. SPE-149709 PA. https://doi.org/10.2118/149709-PA.
Sureshjani, M. H., Behmanesh, H., and Clarkson, C. R. 2013. Multi-Well Gas Reservoirs Production-Data Analysis. Presented at the SPE Unconventional Resources Conference Canada, Calgary, 5–7 November. SPE-167159-MS. https://doi.org/10.2118/167159-MS.
Sureshjani, M. H., Behmanesh, H., and Clarkson, C. R. 2014. A New Semi-Analytical Method for Analyzing Production Data From Constant Flowing Pressure Wells in Gas Condensate Reservoirs During Boundary-Dominated Flow. Presented at the SPE Western North American and Rocky Mountain Joint Meeting, Denver, 17–18 April. SPE-169515-MS. https://doi.org/10.2118/169515-MS.
Sureshjani, M. H., Behmanesh, H., Soroush, M. et al. 2016. A Direct Method for Property Estimation From Analysis of Infinite Acting Production in Shale/Tight Gas Reservoirs. J. Pet. Sci. Eng. 143 (July): 26–34. https://doi.org/10.1016/j.petrol.2016.02.007.
Walsh, M. P. and Lake, L. W. 2003. A Generalized Approach to Primary Hydrocarbon Recovery. Amsterdam: Elsevier.
Walsh, M. P., Ansah, I., and Raghavan, R. 1994. The New, Generalized Material Balance as an Equation of a Straight Line: Part 1—Applications to Undersaturated, Volumetric Reservoirs. Presented at the Permian Basin Oil and Gas Recovery Conference, Midland, Texas, 16–18 March. SPE-27684-MS. https://doi.org/10.2118/27684-MS.
Wyckoff, R. D. and Botset, H. G. 1936. The Flow of Gas-Liquid Mixtures Through Unconsolidated Sands. Physics 7 (9): 325. https://doi.org/10.1063/1.1745402.
Zhang, M. and Ayala, L. F. 2015. Density-Based Production-Data Analysis of Gas Wells With Significant Rock-Compressibility Effects. SPE Res Eval & Eng 18 (2): 205–213. SPE-166320-PA. https://doi.org/10.2118/166320-PA.