A New Method To Predict the Performance of Gas-Condensate Reservoirs
- Ali Al-Shawaf (Saudi Aramco) | Mohan Kelkar (University of Tulsa) | Mohammad Sharifi (Amirkabir University of Technology)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- May 2014
- Document Type
- Journal Paper
- 177 - 189
- 2014.Society of Petroleum Engineers
- 4.6 Natural Gas, 5.3.2 Multiphase Flow, 5.2.1 Phase Behavior and PVT Measurements, 5.6.8 Well Performance Monitoring, Inflow Performance, 5.8.8 Gas-condensate reservoirs, 4.3.4 Scale
- gas condensate , inflow performance relationship
- 5 in the last 30 days
- 861 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
Gas-condensate reservoirs differ from dry-gas reservoirs. The understanding of phase and fluid flow-behavior relationships is essential if we want to make accurate engineering computations for gas-condensate systems. Condensate dropout occurs in the reservoir as the pressure falls below the dewpoint, resulting in significant gas-phase production decreases. The goal of this study is to understand the multiphase-flow behavior in gas-condensate reservoirs and, in particular, to focus on estimating gas-condensate-well deliverability. Our new method analytically generates the inflow-performance-relationship (IPR) curves of gas-condensate wells by incorporating the effect of condensate banking as the pressure near the wellbore drops below the dewpoint. The only information needed to generate the IPR is the rock relative permeability data and a constant-composition expansion (CCE) experiment. We have developed a concept of critical oil saturation near the wellbore by simulating both lean and rich condensate reservoirs and have observed that the loss in productivity caused by condensate accumulation can be closely tied to critical saturation. We are able to reasonably estimate re-evaporation of liquid accumulation by knowing the CCE data. We validated our new method by comparing our analytical results with fine-scale-radial-simulation-model results. We demonstrated that our analytical tool can predict the IPR curve as a function of reservoir pressure. We also developed a method for generating an IPR curve with field data and demonstrated its application with field data. The method is easy to use and can be implemented quickly. Another advantage of this method is that it does not require the knowledge of accurate production data including the varying condensate/gas ratio (CGR).
|File Size||3 MB||Number of Pages||13|
Afidick, D., Kaczorowski, N.J., and Bette, S. 1994. Production Performance of a Retrograde Gas Reservoir: A Case Study of the Arun Field. Paper SPE 28749 presented at the SPE Asia Pacific Oil and Gas Conference, Melbourne, Australia, 7–10 November. http://dx.doi.org/10.2118/28749-MS.
Blom, S.M.P. and Hagoort, J. 1998. The Combined Effect of Near-Critical Relative Permeability and Non-Darcy Flow on Well Impairment by Condensate Drop Out. Res Eval & Eng 1 (5): 421 – 429. http://dx.doi.org/10.2118/51367-PA.
Dyung, T., Vo, J.J., and Raghavan, R. 1987. Performance Prediction for Gas Condensate Reservoir. Paper SPE 16984 presented at the SPE Annual Technical Conference and Exhibition, Dallas, Texas, 27–30 September. http://dx.doi.org/10.2118/16984-MS.
Evinger, H.H. and Muskat, M. 1942. Calculation of Theoretical Productivity Factor. Trans, AIME 146: 126–139.
Fevang, O. and Whitson, C.H. 1996. Modeling Gas Condensate Well Deliverability. Res Eval & Eng 11 (4): 221–230. http://dx.doi.org/10.2118/30714-PA.
Guehria, F.M. 2000. Inflow Performance Relationships for Gas Condensates. Paper SPE 63158 presented at the SPE Annual Technical Conference and Exhibition, Dallas, Texas, 1–4 October. http://dx.doi.org/10.2118/63158-MS.
Kamath, J. 2007. Deliverability of Gas/condensate Reservoirs- Field Experiences and Prediction Techniques. J. Pet Tech 59 (4): 94–99. http://dx.doi.org/10.2118/103433-PA.
Kelkar, M. 2008. Natural Gas Production Engineering. PennWell Corporation.
Mott, R. 1997. Calculating Well Deliverability in Gas Condensate Reservoirs. Paper-104 presented at the IBC Technical Services Conference on Optimization of Gas Condensate Fields, Aberdeen, UK, 26–27 June.
Mott, R. 2003. Engineering Calculations of Gas/condensate Well Productivity. SPE Res Eval & Eng 6 (5): 298–306. http://dx.doi.org/10.2118/86298-PA.
Mott, R.E., Cable, A.S., and Spearing, M.C. 2000. Measurements of Relative Permeabilities for Calculating Gas/condensate Well Deliverability. SPE Res Eval & Eng 3 (6): 473–479. http://dx.doi.org/10.2118/68050-PA.
Sharifi, M. and Ahmadi, M. 2009. Two-phase Flow in Volatile Oil Reservoir Using Two-Phase Pseudo-pressure Well Test Method. J. Cdn. Pet. Tech. 48 (9): 6–11. http://dx.doi.org/10.2118/09-09-06-PA.
Xiao, J.J. and Al-Muraikhi, A. 2004. A New Method for the Determination of Gas Condensate Well Production Performance. Paper SPE 90290 presented at the SPE Annual Technical Conference and Exhibition, Houston, Texas, 26–29 September. http://dx.doi.org/10.2118/90290-MS.