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Sweet Spots
in
Shale Gas and Liquids Plays
Harris Cander
BP America
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Eagle Ford Fluid Fairways
Map published
by EOG
Sweet spot for liquids
Oil > $80 bbl
Gas < $3 mcf
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Eagle Ford liquids sweet spot Gas-Oil Ratio at High Pressure
Reservoir Pressure
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“Unconventional” but still obey principles
Q = k * H *DP
m
Q = well flow rate
k = permeability
H = thickness
DP = Reservoir Pressure – wellbore pressure
m = viscosity
• Viscosity is related to Gas-Oil Ratio…
• Gas-Oil Ratio is related to maturity…
• Pressure is related to maturity and burial and uplift history
• P and m change a lot in a typical shale fairway!
Darcy’s Law
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0.6 0.8 1 1.2 1.4 1.6 1.8
TSI: Vitrinite-ARCO (%Ro)
0.01
0.1
1
10
100
1000
10000
100000
Ins
tan
tan
eo
us
GL
R E
xp
ell
ed
(s
cf/
stb
)
Instantaneous GLR Expelled (scf/stb)
Instantaneous Expelled Fluid Viscosity (cP)
Shale Maturity vs.
Gas-Oil Ratio & Viscosity
Ro Vitrinite Reflectance
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Liquids Rate (BOPD) vs. Gas-Oil Ratio
100
1,000
10,000
100,000
0 500 1000 1500 2000
Gas-Oil
Ratio scf/bbl
Liquids Rate BOPD (IP30)
Liquid
Vapor
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Eagle Ford liquids sweet spot Can we predict composition and pressure?
Reservoir Pressure
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Previous kinetic model Reach “sorption” threshold of kerogen and then “expel petroleum”
Problem:
Source rocks retain more petroleum than previously thought
Expel less than previously thought
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Updated BP model • Storage in organic and mineral matrix porosity
• Different % Petroleum Saturations
– Organic and Mineral matrix porosity
• Calculate Gas-Oil Ratio of Retained and Cumulative Expelled petroleum
Source
interval
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Retained vs. Migrated Gas Oil Ratio BP Eagle Ford Shale model
Gas - Oil
Ratio
scf/bbl
vapor
liquid
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Gas Oil Ratio predicted from Thermal Stress
Ro Vitrinite
GOR scf/bbl
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PVT GOR vs. Predicted GOR scf/bbl Good prediction of composition and phase
Actual: 14,680
Model: 13,200
Actual: 6,509
Model: 4,500
Actual: 1,916
Model: 2,800
PVT data courtesy of Corelab
Predicted Gas-Oil Ratio
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Convert GOR into Viscosity (mobility)
Q = k * H *DP
m
High pressure helps mobility of more viscous liquid phase fluids
Viscosity cp
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Over-pressure in source rocks
• Petroleum generation?
• Rapid burial?
–Compaction disequilibrium
• How is over-pressure
preserved?
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• Hydrocarbon generation
• Bitumen network
• Increase in pore pressure
• Expulsion to other beds
Petroleum generation & over-pressure Research from BP Amoco
Immature – dispersed organic matter
Mature – bitumen network develops
Pyrolysis of Woodford Shale
Lewan, 1985
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Eagle Ford Shale South Texas
A
A’
Eagle Ford Structure (m)
020406080100120140160180
Age
0
5000
10000
15000
20000
De
pth
in
fe
et
PMioceneOlig.EocenePal.L.CretaceousE.CretaceousJurassic
1 – 2 km of uplift in west;
Less in east part of fairway
Eagle Ford
Texas
TIME
DE
PT
H
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NW-SE Dip section
Eagle Ford
Dimmit Webb Maverick
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Over-pressure (mudweight) during Eocene
With petroleum generation & expulsion Eagle Ford
expulsion
Without petroleum generation & expulsion
…Still have overpressure
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Over-pressure and Gas Generation Over-pressure is not linked to gas window
Post-Laramide uplift in west caused loss
of over-pressure and decoupling of GOR
and pressure contours
Over-pressure in the Eagle Ford psi above hydrostatic
85 Ma
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Burial and maturation create over-pressure;
Uplift can destroy it
Time
Depth
0 Ma 100’s Ma
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Sweet Spot Changes due to Price Changes
GOR
scf/bbl
“Sweet Spot” at
high Oil prices
“Sweet Spot” at
high Gas prices
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$weet $pots = Mobility
• Fluid viscosity and reservoir pressure
• Petroleum composition and viscosity can be predicted
– New BP model
– Viscosity and GOR are directly linked to maturity…
• Over-pressure
– Petroleum generation and compaction disequilibrium
– Preserved if uplift is limited
– Must understand burial and uplift history!
• Sweet spots can shift as oil and gas prices change
Q = k * H *DP
m
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Thanks!
Harris Cander BP
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Exhumation and Over-pressure
Fairway Exhumation Over-pressure
Arkoma Woodford > 10,000 ft Mild to none
Fayetteville > 10,000 ft Mild to none
Anadarko Woodford < 6,000 ft High
Haynesville < 7,000 ft High
Eagle Ford < 6,000 ft High
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Instantaneous vs. Cumulative GOR increases during generation
120 C
150 C
180 C
Cumulative
Trap
Trap
Instantaneous
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Exhumation: loss of pressure
Arkoma
High exhumation
Over-pressure lost
Anadarko
Minor exhumation
Over-pressure preserved
Isopach of eroded section
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Drop in Effective Stress in Eagle Ford Preservation of pore throats
Permeability is not just a function of facies or the rock
Permeability is also a function of pore pressure
Depth
(ft)
Effective Stress (psi)
Eagle Ford
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Difference in over-pressure With and without petroleum generation & expulsion
With petroleum
generation & expulsion
Without petroleum
generation & expulsion
Real well data
Model
Real well data
Model
Eagle Ford Eagle Ford
0.74 psi/ft 0.66 psi/ft
14 10 12 14 10 12
De
pth
Mud Weight Mud Weight
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Maturity vs. GOR & Viscosity
100 120 140 160 180 200
Temperature (C)
0.01
0.1
1
10
100
1000
10000
100000
Insta
nta
neo
us G
LR
Exp
ell
ed
(sc
f/s
tb)
Instantaneous GLR Expelled (scf/stb)
Instantaneous Expelled Fluid Viscosity (cP)
Temperature C
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Eagle Ford Gas Flow Rate (mcfd) Low viscosity gas is more mobile
Rate mcfd
1,000
10,000
100,000
100 1000 10000
Liquid
Vapor
GOR
scf/bbl
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Sweet Spot depends on local prices
Reservoir Pressure
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BP scheme also models changes in inorganic
and organic porosity
… with or without over-pressure
0.01 0.1 1
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
Organic porosity
Depth
(m)
Porosity (fraction)
Inorganic
porosity