overview of gas displacement eor
TRANSCRIPT
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Mark Holtz RECS 2012 7 June 2012
Overview of Gas Displacement Enhanced Oil Recovery
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Praxair At A Glance
TEXAS LOUISIANA
Hydrogen
Air Separation Plants
NitrogenOxygen
Industrial Area
GALVESTONBAY
GULF OFMEXICO
BAYTOWN
MONTBELVIEU
CHANNELVIEW
LAPORTE
HOUSTON
GALVESTONTEXAS CITY
PORTARTHUR
PASADENADEERPARK
BAYPORT
SULPHUR
LAKECHARLES
NEDERLAND
SABINELAKE
NEWORLEANS
GEISMAR
BATON ROUGE
245 miles of pipeline serving50 major customers
BEAUMONT
Praxair’s 600 MMCFD H2 System Capacity
Packaged Gases Liquid Supply
Pipline
Onsite
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Upstream Oil and Gas Business
l Enhanced Oil Recovery – Over 30 years experience with Gas
Displacement Recovery (GDR) l Nitrogen l Carbon Dioxide
– More than 25 projects
l Well Stimulation Services
l CO2/N2 EOR Services – Pilots and huff-n-puffs
l CO2 Capture & Purification Exxon Hawkins Field, Injects 80 MMscf/d of N2 at 2,000 psi
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Outline
1. The Petrophysics of Residual Saturation 2. General Applications of Gas
Displacement Recovery (GDR) 3. CO2 EOR Pilot Approach
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Rock-Fluid Property Models
• Wettability • End point fluid characteristics
– Residual oil and gas saturation – End point water saturations
• Oil-water relative permeability • Oil-gas relative permeability • Gas-water relative permeability • Capillary pressure character
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Wettability
• Is defined as the tendency of one fluid to spread on or adhere to a solid surface in the presence of other immiscible fluids.
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Wettability Contact Angle
• Water wet
Grain surface
Water
Oil
• Oil wet
Water
αc αc
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Pore-Scale Trapping results in residual saturation.
Wetting phase
Nonwetting phase trapped
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Wettability Effects on Water Displacing Oil
Time and water encroachment increasing
Water Water Water
Oil Oil Oil
Water wet system
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Wettability Effects on Water Displacing Oil
Water Water Water
Oil Oil
Oil
Time and water encroachment increasing
Oil Wet System
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Wettability and Relative Permeability R
elat
ive
perm
eabi
lity
(%)
Water saturation (%)
100
80
60
40
20
0 0 20 40 60 80 100
Water
Water
Oil Wet Water Wet
Oil
Oil
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48
40
32
Capillary Pressure Curves: Water-Wet and Oil-Wet
24
16
8
0 0 20 40 60 80 100
Water Saturation, %
Cap
illar
y Pr
essu
re, c
m o
f Hg
2 1
48
40
32
24
16
8
0 0 20 40 60 80 100
Water Saturation, % C
apill
ary
Pres
sure
, cm
of H
g
Water-wet Rock (Vernango Core)
After Killins et al. 1953, Dullien 1992
Oil-wet Rock (Tensleep sandstone)
2
1
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Residual Saturation as a Function of Porosity
y = -0.3136Ln(x) - 0.1334 R 2 = 0.8536
0
0.2
0.4
0.6
0.8
1
0 0.1 0.2 0.3 0.4 0.5 0.6 Porosity (fraction)
Res
idua
l Non
wet
ting
phas
e sa
tura
tion
(frac
tion)
Gas Residual saturation to water (fraction) Frio Barrier bar Log. (Gas Residual saturation to water (fraction)) Poly. (Gas Residual saturation to water (fraction)) Log. (Gas Residual saturation to water (fraction))
N = 143
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Gas Displacement Recovery Reserve Growth Applications
• Pressure Maintenance – Oil reservoirs – Pressure maintenance condensate and retrograde
condensate reservoirs • Miscible Displacement • Immiscible Displacement
Ø Patterns Ø Huff n Puff
• Mixed gas Applications Ø Driving agent for slug/buffer Ø Mixed gases for density control
• Gas Assisted Gravity Drainage
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Gas Cap Injection
l Mechanisms – CO2/N2 displacing
methane – Pressure
maintenance for the oil saturated zone.
Oil
CH4 CO2/N2
Prax
air
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Generalized Retrograde Condensate-Gas Phase Diagram
Pres
sure
Cric
onde
nthe
rm
Temperature Reservoir Temperature
Modified from McCain (1973)
Gas
Liquid
Dew point pressure
100
75
50
25
10
0
Pressure depletion
Initial conditions
Surface conditions
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Gas Condensate Pressure Maintenance
l Pressure depletion causes; – Reduction in gas permeability and well productivity – Lower ultimate hydrocarbon recovery 10 to 40 % – Aquifer encroachment
l Screening criteria: 1) Dew point pressure is near the original reservoir pressure, under
saturated by 150 to 300 psi,
2) High condensate yield of 175 bbl/MMSCF produced, 3) High liquid dropout rate with liquid condensation from 20 to 40 %
of the hydrocarbon pore space.
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Gas Displacement Recovery Reserve Growth Applications
• Pressure Maintenance – Oil reservoirs – Pressure maintenance condensate and retrograde
condensate reservoirs • Miscible Displacement • Immiscible Displacement
Ø Patterns Ø Huff n Puff
• Mixed gas Applications Ø Driving agent for slug/buffer Ø Mixed gases for density control
• Gas Assisted Gravity Drainage
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Solvent EOR
5 to 15 % Stability override
Reduces oil viscosity, swells oil, Miscible displacement
Miscible
10 MCF/STB oil produced
5 to 15 % Stability override
Reduces oil viscosity, swells oil
Immiscible
Typical utilization
Typical recovery (%OOIP) Issues
Recovery mechanism Process
Modified From Taber & Martin, 1983
6 MCF/STB oil produced
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CO2 Minimum Misciility Pressure
50
55
60
65
70
75
80
85
90
95
100
1000 1100 1200 1300 1400 1500 1600 1700 1800
Test Pressure, psia
% R
ecov
ery
at 1
.2 H
CPV
of C
O2
Inje
cted
CO2 Thermodynamic MMP
Minimum Miscibility Pressure Estimation
Estimated MMP
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CO2 Miscibility Displacement
l Results in high pore level displacement efficiency.
l Miscibility types including;
– First-contact miscibility – Multi-contact miscibility
l Currently applied as; – WAG – Continuous injection
Producer Injector
Prax
air
Oil CO2 Miscible front
The formation of a single phase diminishes the capillary forces
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Gas Displacement Recovery Reserve Growth Applications
• Pressure Maintenance – Oil reservoirs – Pressure maintenance condensate and retrograde
condensate reservoirs • Miscible Displacement • Immiscible Displacement
Ø Patterns Ø Huff n Puff
• Mixed gas Applications Ø Driving agent for slug/buffer Ø Mixed gases for density control
• Gas Assisted Gravity Drainage
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Immiscible Floods and Pilots
• Dodan Field, Turkey, Turkish Pet., • 9- 15 API, 300 -1000 cp • 60 MMSCF/D ( 1998 production) • Carbonate reservoir, at 1,500 m (4,900 ft) depth
• Lick Creek Field • 17 API, 160 cp • Ss, Arkansas, after 5 years CO2 injection = 14.1 BSCF & 1 MMSTB oil
produced. • Willmington Field pilots
• Fault block 3 tar zone • Fault Block 5, 14 API, 180-410 CP demonstrated incremental tertiary oil recovery
• Ritchie Field • 16 API, 195 cp • Arkansas, CO2 utilization 6.0 Mscf/STB,
• Huntington Beach Field • 14 API, 177 cp oil
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EOR Huff-n-Puff
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Gas Displacement Recovery Reserve Growth Applications
• Pressure Maintenance – Oil reservoirs – Pressure maintenance condensate and retrograde
condensate reservoirs • Miscible Displacement • Immiscible Displacement
Ø Patterns Ø Huff n Puff
• Mixed gas Applications Ø Driving agent for slug/buffer Ø Mixed gases for density control
• Gas Assisted Gravity Drainage
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N2 as Driving Agent for slug/buffer (chase gas)
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St Elaine Pilot Gravity stable N2 after CO2
84.4 metric tons/D CO2 injected or 1/3 Pore volume
9 month pilot
N2 slug after CO2 , CH4 & n-butane mixture
From Palmer et al., 1984,
31
N2 injection rate; 136.1 metric tons/day (2.62 MMSCF/day
Critical velocity: 2.2 ft/d
CO2 front velocity designed at 1.6 ft/d or 70% of critical
0 300 600
N
CO2 Injection Well Producer
8,000
7,800
7,600
7,400
GW
C 7,514
Structure Map 8,000 ft sand
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Gas Displacement Recovery Reserve Growth Applications
• Pressure Maintenance – Oil reservoirs – Pressure maintenance condensate and retrograde
condensate reservoirs • Miscible Displacement • Immiscible Displacement
Ø Patterns Ø Huff n Puff
• Mixed gas Applications Ø Driving agent for slug/buffer Ø Mixed gases for density control
• Gas Assisted Gravity Drainage
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Gravity Drainage Double Displacement Process l The process of gas
displacement of a water invaded oil column has been termed Double Displacement Process (DDP). – The DDP consists of
injecting gas up-dip and producing oil down-dip.
– DDP is efficient gravity drainage of oil with high gas saturation.
– Oil displaces water and gas displaces oil downstructure.
N2 injector Producer
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Gravity Drainage Double Displacement Process (DDP)
l Up dip gas injection into a dipping reservoir is one of the most efficient recovery methods.
– Recovery efficiencies of 85 % to 95 %
l Increases sweep efficiency l SoDDP decrease of 35% ( Hawkins field)
l Increases displacement efficiency – Oil film flow is an important recovery mechanism
l Film flow connects the isolated blobs of residual oil in the presence of gas
– Strong water wet – Positive spreading coefficient
Modified from Ren et al., 2000)
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Gravity Drainage - General Design
l Obtain piston (no gas fingering) like displacement – Horizontal gas-oil contact – Have gravity dominate the gas flow
l Optimize the time between gas injection and oil production. – As fast as possible without gas fingering
l The greater the dip angle the higher the injection & production rates w/o gas fingering
– The greater the dip the more effective the gravity drainage
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Gravity Drainage - General Design
l Critical velocity analytical model
l Simulation model dependent on 3 Phase relative permeability
– Effected by film flow – Effected by saturation history – Typically from 2 phase correlations – Depend on the direction of flow (i.e.,
be directionally anisotropic)
Vc is critical velocity rate (ft/day) Δρ is density difference k is permeability (darcies) θ is dip angle φ is porosity (fraction) Δµ is viscosity difference
µφθρ
Δ
Δ=
sin741.2 kVc
Where
(Hill 1952)
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Praxair GDR Pilot Approach
• Key is proper planning – Determine goals, objectives, and strategy
• Important tasks include: 1) Initial reservoir characterization
• Test interwell connectivity (Interference tests) § Identifying reserve growth method
2) Monitoring program design 3) Facilities design 4) Proper implementation 5) Postmortem evaluation
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CO2 EOR Pumping Setup
Heater
Manifold
Pump
Control house
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Typical CO2 Injection P-T Profile
Tanker
Wellhead Reservoir
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MASDAR/ADCO CO2 Pilot
• Pilot characterizes oil reservoir capacity to store CO2 and impact on EOR.
• Started in November 2009 • Continuous 60 TPD injection rate
@ up to 2700 psi • Praxair employees operate site
24X7 • 2 yr duration • Multiple CO2 Sources
36
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Conclusions l Future reserve additions in large light oil, mature fields will
primarily come from GDR. l Reserve additions will occur through:
– Pressure maintenance – Miscible displacement – Immiscible displacement – Mixed gas Applications – Gravity drainage
l GDR typically increases both sweep and displacement efficiency in oil and gas reservoirs.
l Reserve growth targets can range from 10 to 45 % of OOIP/OGIP
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Seeper Trace
• Detection Equipment • Field Analysis Laboratory
• Leak Monitoring with Perfluorocarbon Tracers
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Questions Tracers Can Answer
• Identify Leaks – Abandoned wells – Well casings – Geologic features
• Positively identify the injected gas • Transport times and pathways • Communication between strata