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CPGE Surfactant/Polymer Flood of Midland Farms Dolomite Core D6 Gary Pope David Levitt Adam Jackson Jon Holder The University of Texas at Austin.

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Presentation on theme: "CPGE Surfactant/Polymer Flood of Midland Farms Dolomite Core D6 Gary Pope David Levitt Adam Jackson Jon Holder The University of Texas at Austin."— Presentation transcript:

1 CPGE Surfactant/Polymer Flood of Midland Farms Dolomite Core D6 Gary Pope David Levitt Adam Jackson Jon Holder The University of Texas at Austin

2 CPGE Outline Objective Phase behavior formulation Core flood design Results Conclusions

3 CPGE Objectives Achieve initial oil saturation and residual oil saturation to water similar to MF reservoir values and at similar pressure gradients Recover 90% of waterflood residual oil with surfactant and polymer Achieve low surfactant retention

4 CPGE Phase Behavior and Surfactant Formulation Criteria: Low viscosity Low interfacial tension High solubilization ratio Short equilibration time [Photo] 0.75% N67-7PO, 0.25% IOS C1518, 2% SBA (WOR 1:1) with MF3 at 38C after 6 days Scan from 2 - 6% Equilibration time ~ 12 (days) Solubilization,  = 12 (cc/cc)

5 CPGE Solubilization and Optimal Salinity Solubilization (cc/cc)

6 CPGE HPAM Polymer Hydrolyzed Polyacrylamide (HPAM) Flopaam 3330S from SNF Floeger

7 CPGE HPAM Polymer

8 CPGE HPAM Polymer

9 CPGE Midland Farms Dolomite Core Design and Configuration  = 0.18 k brine = 166 md k ro = 0.40 k rw = 0.03 S wi = 0.26 S orw = 0.39 Formation Brine: 6.1% TDS (8:1 NaCl:CaCl 2 )

10 CPGE Injected Fluids Pore VolumesMixture % N67[7PO], 0.25% IOS C1518, 2% SBA 0.02% Na2CO3, 4.45% NaCl 1500 ppm Flopaam 3330S 0.22% SBA 3.05% NaCl 1500 ppm Flopaam 3330S % NaCl 1200 ppm Flopaam 3330S

11 CPGE Oil Flood Pressures

12 CPGE Water Flood Pressures

13 CPGE Sulfate Detected in Produced Formation Brine Effluent SampleSulfate Concentration (ppm) Samples taken from tubes preceding oil breakthrough

14 CPGE Oil Recovery Results Free Oil = 90%Oil from Emulsion = 5%

15 CPGE Surfactant Recovery Results Surfactant Retention: 0.43 mg/g

16 CPGE Surfactant/Polymer Pressure Results

17 CPGE Post-flood Polymer Assessment Polymer Resistance Factor (R f ): R f = (  P p /  P w ) q, Sw = 23/0.3 = 87 Polymer Permeability Reduction Factor (R k ): R k = R f / (  p /  w ) = 87/(5.5/0.911) = 14.5 Previous core flood indicated: R k = 2 (Prior HPAM used 2000 ppm Alcomer 60RD)

18 CPGE Conclusions Cumulative oil recovery of 95% S orc = 0.01 High oil recovery in a dolomite without sodium carbonate 50% of the surfactant was recovered No plugging occurred Anhydrite is present in core Sodium carbonate can not be used Polymer concentration may be reduced


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