the sleeping giant elm coulee field: facies and petophysical...
TRANSCRIPT
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Adrian Almanza
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Location
Stratigraphy
Structure
Petrophysics
Pressure
Production
Conclusions
Future Plans
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~400 digital logs from TGS
4 Cores with porosity, permeability and XRD analysis: Jackson Rowdy, Lonetree, Foghorn, Brutus
2 Cores previously examined by the CSM consortium with porosity and permeability: Viara, Williams
IHS production data for the Elm Coulee field
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Elm Coulee Located in Richland County, Montana
Location of Digital log and Core Wells
Contours on top of Bakken Shale
Montana North Dakota
Elm Coulee
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F - Brachiopod-silty dolostone.
E - Thin-bedded Burrowed and biotrubated silty dolostone.
C – Rhythmic mm-cm laminated silty dolostone
A – Brachiopod-rich silty dolostone. Bioturbated in some areas. Contains crinoids and echinoderms fragments
B – Burrowed and biotrubated silty dolostone. Contains abundant clay rich, compacted helminthopsis and scalarituba burrows
Foghorn
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Jackson Rowdy Foghorn Lonetree Brutus
CSM B CSM C
Three Forks
Upper BKKN Shale
Lower BKKN Shale
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NW SE
CSM B CSM C
Three Forks
Upper BKKN Shale
Lower BKKN Shale
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SW NE
CSM B
CSM C
Three Forks
Upper BKKN Shale
Lower BKKN Shale
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SW NE
CSM B CSM C
Three Forks
Upper BKKN Shale
Lower BKKN Shale
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NAME VALUE DESCRIPTION
GR CLEAN 20 Gamma Ray clean
GR SHALE 150 Gamma Ray Shale
RhoF 1 Bulk Density Fluid
RhoM 2.71 Bulk Density Matrix
Rw .02 Formation Water Resistivity
a 1 Archie “a”
m 2 Archie “m”
n 1.74 Archie “n”
Rock Typing, Facies and Core Relationships
Calculations: Sw,PHIA,SoPhiH
XRD with Log Values
Petrophysical Maps
Petrophysical Parameters
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0.001
0.01
0.1
1
0 0.01 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.09 0.1
Pe
rme
ab
ilit
y%
Porosity
Porosity vs Permeability(H)
CSM_A
CSM_B
CSM_C
CSM_E+F
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y = 6.7868x + 0.0203 R² = 0.9324
0
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0 0.005 0.01
Foghorn_CSM_B
Foghorn_CSM_B
y = 1.3346x + 0.0631 R² = 0.5557
0
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0 0.005 0.01
Lonetreee_CSM_B
Lonetreee_CSM_B
y = -0.0027x + 0.0523 R² = 0.044
0
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0 0.05 0.1
Brutus_CSM_B
Brutus_CSM_B
y = 0.1777x + 0.0758 R² = 0.1652
0
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0.1
0 0.02 0.04 0.06
Jackson_Rowdy_CSM_B
Jackson_Rowdy_CSM_B
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y = 0.0059ln(x) + 0.0222 R² = 0.861
0.0001
0.001
0.01
0.1
1
0 0.02 0.04 0.06 0.08
Foghorn_CSM_B
Foghorn_CSM_B
y = 0.0078ln(x) + 0.114 R² = 0.7898
0.0001
0.001
0.01
0.1
1
0 0.005 0.01 0.015 0.02
Lonetree_CSM_B
Foghorn_CSM_B
y = 0.0663ln(x) + 0.2235 R² = 0.2796
0.0001
0.001
0.01
0.1
1
0 0.02 0.04 0.06 0.08 0.1
Brutus_CSM_B
Brutus_CSM_B
y = 0.0331ln(x) + 0.1053 R² = 0.2415
0.001
0.01
0.1
1
0 0.05 0.1
Jackson_Rowdy_CSM_B
Jackson_Rowdy_CSM_B
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Jackson Rowdy Foghorn Lonetree Brutus
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Jackson Rowdy Foghorn Lonetree Brutus
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Jackson Rowdy Foghorn Lonetree Brutus
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Middle Bakken Reservoir
Water Saturation
Average 68%
Maximum 100%
Minimum 0.1%
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Middle Bakken Reservoir
Resistivity (Ohmm)
Average 84
Maximum 723
Minimum 5
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Reservoir Acres OOIP BBL/Acre MMbbl/Sec
Middle Bakken 490,113 ~1,500,000,00o 3050 2
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DST data: Build up profiles
Regional pressure map with DST and Mudweights.
Vaira #44-24: Pressure Gradient 0.53 psi/ft
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Top BKKN Pressure Gradient
Average .54
Maximum .551
Minimum .525
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0
100
200
300
400
500
600
700
800
0 100000 200000 300000 400000 500000 600000 700000 800000
# o
f W
ell
s
Barrels of Oil
Oil Production vs # of Wells
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2 Wells with Production
Elm Coulee Production and spatial distribution
Brutus: Cumulative Oil 25,000 bbls Cumulative Water 29,581 bbls
Foghorn: Cumulative Oil 92,000 bbls Cumulative Water 10,856 bbls
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Elm Coulee acts like a traditional reservoir
SoPhiH and production are in agreement
Common pressure regime throughout the field
Upper shale shows invasion profile and can contribute to overall oil production.
Porosity and permeability correlations may need to be logarithmic and confined to core reservoir areas
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Build an integrated geologic petrel 3D model
Import wells and surfaces
Facies mapping with geologic properties: Sw, porosity, permeability.
Work with petroleum engineering department to run a production history match model.
Work on a secondary recovery model that could help with potential water or CO2 flood.
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Mike Johnson
Consulting Geologist
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Middle Bakken Reservoir
Sonic (US/F)
Average 59
Maximum 70
Minimum 55
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