The Sleeping Giant Elm Coulee Field: Facies and Petophysical...

Adrian Almanza

Location

Stratigraphy

Structure

Petrophysics

Pressure

Production

Conclusions

Future Plans

~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

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

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

Jackson Rowdy Foghorn Lonetree Brutus

CSM B CSM C

Three Forks

Upper BKKN Shale

Lower BKKN Shale

NW SE

CSM B CSM C

Three Forks

Upper BKKN Shale

Lower BKKN Shale

SW NE

CSM B

CSM C

Three Forks

Upper BKKN Shale

Lower BKKN Shale

SW NE

CSM B CSM C

Three Forks

Upper BKKN Shale

Lower BKKN Shale

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

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

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

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

Jackson Rowdy Foghorn Lonetree Brutus

Jackson Rowdy Foghorn Lonetree Brutus

Jackson Rowdy Foghorn Lonetree Brutus

Middle Bakken Reservoir

Water Saturation

Average 68%

Maximum 100%

Minimum 0.1%

Middle Bakken Reservoir

Resistivity (Ohmm)

Average 84

Maximum 723

Minimum 5

Reservoir Acres OOIP BBL/Acre MMbbl/Sec

Middle Bakken 490,113 ~1,500,000,00o 3050 2

DST data: Build up profiles

Regional pressure map with DST and Mudweights.

Vaira #44-24: Pressure Gradient 0.53 psi/ft

Top BKKN Pressure Gradient

Average .54

Maximum .551

Minimum .525

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

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

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

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.

Mike Johnson

Consulting Geologist

Middle Bakken Reservoir

Sonic (US/F)

Average 59

Maximum 70

Minimum 55