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

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

May 13, 2023 323 likes •556 views

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

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SLIDE 1

Case Study

Ash Minnelusa Unit Sweep Improvement

Jim im Ma Mack MTech V Ventu tures L LLC

Denver, Colorado

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SLIDE 2

Ash Minnelusa Sand Unit

R 69 W T 52 N

WY WY Campbell Co. Campbell Co.

28 27

#28-1 #27-1 42-28

SI

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SLIDE 3

Ash Minnelusa Sand Unit Reservoir Data

General:

Discovery Formation Type Average Depth Primary Producing Mech Well Spacing July 3, 1987 Minnelusa “B” Sandstone Stratigraphic 7775 Rock and Fluid Expansion 40 Acre

Rock Properties:

Permeability Range Average Permeability Permeability Variation Average Porosity Average Water Saturation Temperature 5 – 3000 md 300 md 0.746 16.3% 15.5% 140°F

Fluid Properties:

Formation Volume Factor Oil Viscosity Oil Gravity 1.01 30 cps 20°API

Injection Data:

Cumulative Polymer Cumulative Water Cumulative Total 33.6% PV 138.4% PV 172.0%PV

Recovery Data:

OOIP Primary Recovery Current Oil Recovery 2,170 MSTBO 14.1% OOIP 45.4% OOIP

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SLIDE 4

Total Field Production

100,000 10,000 1000 100 10 1 May 86 Aug 87 Dec 88 May 89 Aug 90 Sept 91 Jan 93 Monthly Production & Conc (mg/L)

Ash Minnelusa Sand Unit

BWPM BOPM

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SLIDE 5

Ash Minnelusa Sand Unit Polymer-Augmented Processes

Process BBLS % Pore Volume

  • Avg. Polymer

Conc, mg/L Mobility Control 424,598 16.3 705

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SLIDE 6

Total Field Production

100,000 10,000 1000 100 10 1 Jan. 87 Monthly Production (BBLS, Conc, mg/L)

Ash Minnelusa Sand Unit

Jan. 89 Jan. 91 Jan. 93 Jan. 95 Jan. 97 100 10 1 0.1 Input / Output Ratio

BOPM BWPM Input / Output

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SLIDE 7

Production Efficiency

10 1 0.1 0.01 100 200 300 400 500 Cumulative Oil Recovery (MBBLS) Water – Oil Ratio

Ash Minnelusa Sand Unit

Start Mobility Polymer 600

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SLIDE 8

Ash Minnelusa Sand Unit

2500 2000 1500 1000 500 200 400 600 800 1000 1200 Cumulative Injection (MBBLS) Cumulative Pressure, PSI-Days (M)

Ash #1-27 Hall Plot

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SLIDE 9

Injection Wellhead Pressure and Producing Well Hydrostatic Pressure

2500 2000 1500 1000 500 100 200 300 400 Cumulative Injection (MBBLS) Injection Well & Prod. Hydrostatic Pressure (psi) Hydrostatic Pressure (psi) Injection Pressure (psi)

Ash Minnelusa Sand Unit

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SLIDE 10

Ash Minnelusa Sand Unit Polymer-Augmented Processes

Process BBLS % Pore Volume

  • Avg. Polymer

Conc, mg/L Mobility Control 424,598 16.3 705 CDG 180,000 6.9 431

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SLIDE 11

Ash Minnelusa Sand Unit

2500 2000 1500 1000 500 200 400 600 800 1000 1200 Cumulative Injection (MBBLS) Cumulative Pressure, PSI-Days (M)

Ash #1-27 Hall Plot

Start CDG’s

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SLIDE 12

Total Field Production

100,000 10,000 1000 100 10 1 Jan. 87 Monthly Production (BBLS, Conc, mg/L)

Ash Minnelusa Sand Unit

Jan. 89 Jan. 91 Jan. 93 Jan. 95 Jan. 97 100 10 1 0.1 Input / Output Ratio Start CDG’s

BOPM BWPM Input / Output Chloride (mg/L) Polymer (mg/L)

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SLIDE 13

Production Efficiency

10 1 0.1 0.01 100 200 300 400 500 Cumulative Oil Recovery (MBBLS) Water – Oil Ratio Start CDG’s

Ash Minnelusa Sand Unit

Start Mobility Polymer 600

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SLIDE 14

Ash Minnelusa Sand Unit Polymer Augmented Processes

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

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SLIDE 15

Ash Minnelusa Sand Unit

2500 2000 1500 1000 500 200 400 600 800 1000 1200 Cumulative Injection (M BBLS) Cumulative Pressure, PSI-Days (M) End CDG’s

Ash #1-27 Hall Plot

Bulk Gels MARCIT Start CDG’s

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SLIDE 16

Total Field Production

100,000 10,000 1000 100 10 1 Jan. 87 Monthly Production (BBLS, Conc, mg/L) End CDG’s Bulk Gels MARCIT

Ash Minnelusa Sand Unit

Jan. 89 Jan. 91 Jan. 93 Jan. 95 Jan. 97 Jan. 99 100 0.1 Input / Output Ratio Start CDG’s

BOPM BWPM Input / Output Chloride (mg/L) Polymer (mg/L)

10 1

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SLIDE 17

Production Efficiency

10 1 0.1 0.01 100 200 300 400 500 Cumulative Oil Recovery (MBBLS) Water – Oil Ratio Bulk Gels MARCIT

Ash Minnelusa Sand Unit

Start WF Start Mobility Polymer 600 700 End CDG’s Start CDG’s

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SLIDE 18

Injection Efficiency

400 300 100 0.0 200 400 600 800 1000 Cumulative Injection (BBLS) Cumulative Oil (MBBLS)

Ash Minnelusa Sand Unit

1200 200 End CDG’s Bulk Gels MARCIT Start CDG’s

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SLIDE 19

Total Field Production

100 1000 10000 100000

Jan- 87 Jan- 88 Jan- 89 Jan- 90 Jan- 91 Jan- 92 Jan- 93 Jan- 94 Jan- 95 Jan- 96 Jan- 97 Jan- 98 Jan- 99 Jan- 00 Jan- 01 Jan- 02 Jan- 03 Jan- 04 Jan- 05 Jan- 06 Jan- 07 Jan- 08 Jan- 09 Jan- 10 Jan- 11 Jan- 12 Jan- 13 Jan- 14

Ash Minnelusa Unit - Field Production

Oil Production - BOPM Water Production - BWPM

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SLIDE 20

Production Efficiency

200000 400000 600000 800000 1000000 1200000

WOR Cumulative Oil Recovery

Ash Minnelusa Unit Water-Oil Ratio vs. Cumulative Oil Recovery

> 400,000 STB Incremental Oil

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SLIDE 21

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.