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Robert C. Trentham, DGS Center for Energy and Economic Diversification

Significant New “Learings” From An Integrated Study Of An Old Field, Foster/South Cowden Field (Grayburg & San Andres), Ector County, Texas DE-FC22-93BC14982. Robert C. Trentham, DGS Center for Energy and Economic Diversification University of Texas of the Permian Basin. Project Results.

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Robert C. Trentham, DGS Center for Energy and Economic Diversification

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  1. Significant New “Learings” From An Integrated Study Of An Old Field, Foster/South Cowden Field (Grayburg & San Andres), Ector County, TexasDE-FC22-93BC14982 Robert C. Trentham, DGS Center for Energy and Economic Diversification University of Texas of the Permian Basin

  2. Project Results • 290,000 BO Incremental Production 1996 to present • >650,000 BO Incremental Reserves • 3 Re-entries • 4 New Drills • >12 Workovers • Economic life of field extended from 9 to 16 years • Sold to Oxy for well above decline curve price.

  3. Sec 36 Production 1977 to 1993

  4. Bottom Line

  5. “Learnings” Came in All Areas • Reservoir Characterization • Well Testing • Recompletions • Production

  6. Queen Upper Grayburg –Main Pay Lower Grayburg – Minor Pay San Andres – Large OOIP Type Log

  7. FOSTERFIELD

  8. GEOLOGICAL MODEL 3D SEISMIC / INVERSION MODELING FLOW MODELING HISTORY MATCH SIMULATION TESTING, WELL WORK, MONITORING OLD WATERFLOOD CROSS FLOW BETWEEN ZONES NO FRACTURE STIMULATIONS BHP DISCREPANCIES LOW PERMEABILLLTY WHERE DID THE WATER GO? OPEN HOLES / CASED HOLES INTEGATED STUDY Problems Solutions

  9. Discovered 1939 40 Acre spacing Nitro Open Holes Waterflood 1962 20 Acres 1979 Laguna 1992 DOE 1994 Oxy 2002

  10. Reservoir Characterization • San Andres Reservoir – Over Estimates and Under Achievement • Barriers to vertical flow • Inversion Modeling to porosity maps • Seismic Velocity related to Neutron Density Porosity

  11. Porosity vs. Permeability

  12. Seismic Inversion Modeling

  13. Porosity - Inversion vs. log Seismic Inversion Well Log

  14. Well Testing • Water Chemistry • Inefficient sweep • Backup for well testing & workover results • Bottom Hole Pressure Test results • Complex layering of reservoir • Cross flow • Low permeability = Longer test duration • Production tests • 3 day minimum

  15. HC03 S04 CL CA MG NA TDS UPPER GRAYBURG 170 2990 13500 1530 450 7750 26390 LOWER GRAYBURG 386 2632 20295 1889 664 11245 37332 SAN ANDRES 980 3881 33846 2507 762 19855 61831 INJECTION WATER 793 3100 32000 2646 947 17757 57244 CANYON 329 1104 76532 5880 692 42193 126693 ELLENBURGER 439 1459 63917 3840 972 36064 106691

  16. Wells in the same ¼ section 2124 # 544 # 1534 # 955 #

  17. Dual Zone Test

  18. After CIBP

  19. Same Well After Re-frac

  20. Recompletions/Workovers • 1955 to 1982 Fracture Stimulation are closed, healed or scaled over • Acid Stimulations unsuccessful in contacting reservoir • Success rate can be estimated and candidates ranked by Bottom Hole Pressure, Water Chemistry and Production Tests

  21. Brock Lease Workover Results

  22. Production • Outcome of fracture stimulation is proportional to bottom hole pressure and Oil/Water production rates prior to treatment • Flowing water recoveries do not condemn a well. Some wells produce many times load and have to have fluid level drop below 1000’ from surface before producing OIL!

  23. Bottom Line

  24. $ucce$$ful Project? PRODUCTION BEFORE WELL WORK (UPPER GRAYBURG ONLY) 37 BO, 9 MCF, 181 BW INITIAL PRODUCTION AFTER WORK 467 BO, 145 MCF, 3167 BW CURRENT PRODUCTION RATE 280 BO, 65 MCF, 2323 BW

  25. Acknowledgements • Dick Weinbrandt • Bill Robinson • DOE Tulsa office • The Staff of Laguna Petroleum • Baker-Hughes (previously Scientific Software Intercorp) • Paul Laverty • Jim Reeves and Hoxie Smith who conceived and managed the project thru phase I

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