An Integrated Model for History Matching and Predicting Reservoir Performance of Gas/Condensate Wells
- Ahmed M. Farid (Cairo University) | Ahmed El-Banbi (Cairo University) | A A Abdelwaly (Cairo University)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- September 2013
- Document Type
- Journal Paper
- 412 - 422
- 2013. Society of Petroleum Engineers
- 4.6 Natural Gas, 3.3.6 Integrated Modeling, 5.2.2 Fluid Modeling, Equations of State, 5.5 Reservoir Simulation, 5.2.1 Phase Behavior and PVT Measurements, 5.8.8 Gas-condensate reservoirs, 5.5.8 History Matching
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- 866 since 2007
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The depletion performance of gas/condensate reservoirs is highly influencedby changes in fluid composition below the dewpoint. The long-term prediction ofcondensate/gas reservoir behavior is therefore difficult because of thecomplexity of both composition variation and two-phase-flow effects. In thispaper, an integrated model was developed to simulate gas-condensatereservoir/well behavior. The model couples the compositional material balanceor the generalized material-balance equations for reservoir behavior, thetwo-phase pseudo integral pressure for near-wellbore behavior, and outflowcorrelations for wellbore behavior. An optimization algorithm was also usedwith the integrated model so it can be used in history-matching mode toestimate original gas in place (OGIP), original oil in place (OOIP), andproductivity-index (PI) parameters for gas/condensate wells. The model also canbe used to predict the production performance for variable tubing head pressure(THP) and variable production rate. The model runs fast and requires minimalinput. The developed model was validated by use of different simulation casesgenerated with a commercial compositional reservoir simulator for a variety ofreservoir and well conditions. The results show a good agreement between thesimulation cases and the integrated model. After validating the integratedmodel against the simulated cases, the model was used to analyze productiondata for a rich-gas/condensate field (initial condensate/gas ratio of 180 bbl/MMscf). THP data for four wells were used along with basic reservoir andproduction data to obtain original fluids in place and PIs of the wells. Theestimated parameters were then used to forecast the gas and condensateproduction above and below the dewpoint. The model is also capable ofpredicting reservoir pressure, bottomhole flowing pressure, and THP and canaccount for completion changes when they occur.
|File Size||1 MB||Number of Pages||11|
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