Case Study Jim im Ma Mack MTech V Ventu tures L LLC Denver, - PowerPoint PPT Presentation

Ash Minnelusa Unit Sweep Improvement Case Study Jim im Ma Mack MTech V Ventu tures L LLC Denver, Colorado

Ash Minnelusa Sand Unit WY WY R 69 W Campbell Co. Campbell Co. 42-28 SI T 28 27 52 N #28-1 #27-1

Ash Minnelusa Sand Unit Reservoir Data Discovery July 3, 1987 Formation Minnelusa “B” Sandstone Type Stratigraphic General: Average Depth 7775 Primary Producing Mech Rock and Fluid Expansion Well Spacing 40 Acre Permeability Range 5 – 3000 md Average Permeability 300 md Permeability Variation 0.746 Rock Properties: Average Porosity 16.3% Average Water Saturation 15.5% Temperature 140 ° F Formation Volume Factor 1.01 Fluid Properties: Oil Viscosity 30 cps Oil Gravity 20 ° API Cumulative Polymer 33.6% PV Injection Data: Cumulative Water 138.4% PV Cumulative Total 172.0%PV OOIP 2,170 MSTBO Primary Recovery 14.1% OOIP Recovery Data: Current Oil Recovery 45.4% OOIP

Total Field Production Ash Minnelusa Sand Unit 100,000 Monthly Production & Conc (mg/L) BOPM 10,000 1000 100 BWPM 10 1 May Aug Dec May Aug Sept Jan 86 87 88 89 90 91 93

Ash Minnelusa Sand Unit Polymer-Augmented Processes % Pore Avg. Polymer Process BBLS Volume Conc, mg/L Mobility 424,598 16.3 705 Control

Total Field Production Ash Minnelusa Sand Unit 100,000 100 Monthly Production (BBLS, Conc, mg/L) 10,000 Input / Output Ratio 10 1000 100 1 10 BOPM BWPM Input / Output 1 0.1 Jan. Jan. Jan. Jan. Jan. Jan. 87 89 91 93 95 97

Production Efficiency Ash Minnelusa Sand Unit 10 Water – Oil Ratio 1 0.1 Start Mobility Polymer 0.01 0 100 200 300 400 500 600 Cumulative Oil Recovery (MBBLS)

Ash Minnelusa Sand Unit Ash #1-27 Hall Plot 2500 Cumulative Pressure, PSI-Days (M) 2000 1500 1000 500 0 0 200 400 600 800 1000 1200 Cumulative Injection (MBBLS)

Injection Wellhead Pressure and Producing Well Hydrostatic Pressure Ash Minnelusa Sand Unit Injection Well & Prod. Hydrostatic Pressure (psi) 2500 2000 Hydrostatic Pressure (psi) 1500 1000 500 Injection Pressure (psi) 0 0 100 200 300 400 Cumulative Injection (MBBLS)

Ash Minnelusa Sand Unit Polymer-Augmented Processes % Pore Avg. Polymer Volume Conc, mg/L Process BBLS Mobility 424,598 16.3 705 Control CDG 180,000 6.9 431

Ash Minnelusa Sand Unit Ash #1-27 Hall Plot 2500 Cumulative Pressure, PSI-Days (M) 2000 1500 1000 500 Start CDG’s 0 0 200 400 600 800 1000 1200 Cumulative Injection (MBBLS)

Total Field Production Ash Minnelusa Sand Unit 100,000 100 Monthly Production (BBLS, Conc, mg/L) Start CDG’s 10,000 Input / Output Ratio 10 1000 100 1 BOPM BWPM 10 Input / Output Chloride (mg/L) Polymer (mg/L) 1 0.1 Jan. Jan. Jan. Jan. Jan. Jan. 87 89 91 93 95 97

Production Efficiency Ash Minnelusa Sand Unit 10 Water – Oil Ratio 1 Start CDG’s 0.1 Start Mobility Polymer 0.01 0 100 200 300 400 500 600 Cumulative Oil Recovery (MBBLS)

Ash Minnelusa Sand Unit Polymer Augmented Processes % Pore Avg Polymer Process BBLS Volume Conc, mg/L Mobility 424,598 16.3 705 Control CDG 180,000 6.9 431 1,500 2,250 Bulk Gel 10,192 0.4 3,000 (MARCIT) 4,000

Ash Minnelusa Sand Unit Ash #1-27 Hall Plot 2500 Cumulative Pressure, PSI-Days (M) 2000 1500 1000 End CDG’s 500 Bulk Gels MARCIT Start CDG’s 0 0 200 400 600 800 1000 1200 Cumulative Injection (M BBLS)

Total Field Production Ash Minnelusa Sand Unit 100,000 100 Monthly Production (BBLS, Conc, mg/L) Bulk Gels MARCIT Start CDG’s 10,000 Input / Output Ratio 10 1000 End CDG’s 100 1 BOPM BWPM 10 Input / Output Chloride (mg/L) Polymer (mg/L) 1 0.1 Jan. Jan. Jan. Jan. Jan. Jan. Jan. 87 89 91 93 95 97 99

Production Efficiency Ash Minnelusa Sand Unit 10 End CDG’s Water – Oil Ratio 1 Bulk Gels MARCIT Start CDG’s 0.1 Start WF Start Mobility Polymer 0.01 0 100 200 300 400 500 600 700 Cumulative Oil Recovery (MBBLS)

Injection Efficiency Ash Minnelusa Sand Unit 400 End CDG’s Cumulative Oil (MBBLS) 300 Bulk Gels MARCIT 200 Start CDG’s 100 0.0 1200 0 200 400 600 800 1000 Cumulative Injection (BBLS)

Total Field Production Ash Minnelusa Unit - Field Production Oil Production - BOPM Water Production - BWPM 100000 10000 1000 100 Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- Jan- 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14

Production Efficiency Ash Minnelusa Unit Water-Oil Ratio vs. Cumulative Oil Recovery > 400,000 STB Incremental Oil WOR Cumulative Oil Recovery 0 200000 400000 600000 800000 1000000 1200000

Ash Minnelusa Unit Conclusions • Monitor, monitor, monitor. Make changes based upon reservoir response • Improved understanding of the problem improves process application and results • Volumetric sweep (gels) should be applied before mobility control • Implement gel processes early for maximum benefits • Incremental oil expected to exceed 400,000 BBLS (18.4% OOIP) for $0.88/BBL • Field experience is critical with gel processes. Experience at Ash can be applied to other reservoirs.