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Transcript of Oil Zone of Hess’s Seminole Unit Library/Events/2016/fy16 cs rd/Wed... · Oil Zone of Hess’s...
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Optimizing CO2 Sweep based on Geochemical,
and Reservoir Characterization of the Residual
Oil Zone of Hess’s Seminole Unit
Project Number: DE-FE0024375
Ian Duncan
Research Scientist
Bureau of Economic Geology, University of
Texas at Austin
U.S. Department of Energy
National Energy Technology Laboratory
DE-FOA0001110 Kickoff Meeting
December 4, 2014
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Presentation Outline
• Benefit to the Program
• Project Overview: Goals and Objectives
• Expected Outcomes
• Technical Status
• Accomplishments
• Summary
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Benefit to the Program
• Supports DOE’s Programmatic goal No. 2, to
“Develop technologies to improve reservoir
storage efficiency while ensuring containment
effectiveness”.
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Project Overview: Goals and Objectives
Project objective: “To improve the understanding
of how much CO2 can be stored in residual oil
zones (ROZ) given current practice and how much
this could be increased, by using strategies to
increase sweep efficiency”.
These same strategies will increase the efficiency
of oil production.
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Technical Status
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GEOLOGY of SEMINOLE UNIT
Seismic and geological analysis show
that Seminole a carbonate ramp
reservoir, one of several isolated
platforms built during the lower San
Andres and became linked with the rest
of the platform during progradation of
the upper San Andres sequence.
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From Hess Unpublished data
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A UNIQUE DATA SET
824 wells within Seminole San Andres Unit:
• Cores from 66 wells, 17,556 feet total,
complete ROZ core total 3,297 feet.
• Cores through entire MPZ for 24 wells
• Cores through entire ROZ for 12 wells
• Cores with full MPZ & ROZ for 5 wells
• 5 Sponge cores
• 7 cores with SCAL10
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• Core Analyses:
~17,000 core plug analyses for porosity,
permeability, grain density, and fluid saturations,
as well as 148 MICP analyses;
Wireline Logs:
Gamma Ray: 612 wells ; Density Porosity: 283
wells; Neutron Porosity: 296 wells; Sonic Porosity:
294 wells; Caliper: 408 wells; SP: 33 wells; Shallow
Resistivity: 235 wells; Deep Resistivity: 252 wells;
Photoelectric: >68 wells
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DEVELOPING A STATIC
RESERVOIR MODEL
• Geologic logging cores… new facies
interpretations… new modern analogues
• New approach to upscaling porosity and
permeability
• New analysis of petrophysical data.
• Extensive new lab measurements of
permeability, compressive strength,
seismic velocities, electric resistivity, and
NMR.12
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Seminole Unit core being
logged
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REINTERPRETING
GEOLOGIC FACIES
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UNDERSTANDING RESERVOIR
PERMEABILITY
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Core Plug Porosity vs. Permeability – SSAU 3123R02
100.00
10.00
1.00
0.10
0.01
0.00
0.00 5.00 10.00 15.00 20.00 25.00
Porosity, %
Perm
eab
ilit
y,
mD
Source: SPE, 2010, Honarpour, M. M., and others
QAe4803
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Vertical vs. Horizontal Permeability – Full Core SSAU-3903
1000.000
100.000
10.000
1.000
0.100
0.010
0.01 0.10 1.00 10.00 100.00 1000.00
Horizontal
permeability, mD
Ve
rtic
al
perm
eab
ilit
y,
mD
Source: SPE, 2010, Honarpour, M. M., and others
QAe4803
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Whole Core vs. Plug Porosity-Permeability
100
10
1
0.1
0.01
0.001
0 5 10 15 20 25
Porosity, %
Perm
eab
ilit
y,
mD
1000
Core plug
Whole core
Source: SPE, 2010, Honarpour, M. M., and others
QAe4803
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LATERAL PERMEABILITY VARIATION SURFACE OUTCROP
Source: SPE, 2010, Honarpour, M. M., and others
QAe4803
10,000
1000
100
10
1
0 200 400 600 800 1000
Sample position (ft)
Perm
eab
ilit
y,
mD
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THE UPSCALING PROBLEM
• Typically in building a static reservoir
model there are 10 or more times
resolution in permeability measurements
as the vertical dimensions of model cells
• Upscaling is the key step in all simulation
modeling for EOR and CO2 sequestration
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From: Flodin et al, 2004
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Harmonic Mean
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Geometric Mean
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SPATIAL VARIATION HIGH PEREABILITY
QAe5000
Layering
Baffles
Patches
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PERMEABILITY DEFICIT
DISORDER
• Reservoir simulations of major
Permian Basin oil fields cannot match
observed data unless much higher
permeability magnitudes are used in
simulations.
• Typical “Permeability Multipliers” used
are between 2 and 10.28
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CUMULATIVE WATER PRODUCTION VERSUS PERMEABILITY
MULTIPLIER, FULLERTON FIELD,
80,000
40,000
0
1940 1980 2000 2020
Cu
mu
lati
ve w
ate
r
pro
du
cti
on
(b
bl)
120,000
Modified from Wang and Lucia, 2013
QAe5000
Year
1960
No multiplier
× 25
× 30
Field data
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Impact of Fracture Permeability
Total permeability ranges between 2 and 10 times larger than the matrix permeability as a result of natural fractures….
From Philip (2005)
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CAN SULFUR BE USED TO TRACE
HIGH PERMEABILITY PATHWAYS?
• In Permian Basin ROZ oil appears higher
in sulfur (native sulfur replaces anhydrite)
• In Seminole pyrite often found along
stylolites, reflecting H2S.
• Currently investigating distribution of sulfur
compounds and H2S within reservoir.
• Sulfur isotope study being intiated.
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API vs. Oil Sulfur Content
0.04
0.03
0.02
0.01
0
20 30 40 50 60
API oil gravity
Cru
de o
il s
ulf
ur
co
mp
osit
ion
(rati
o)
After Logan, 2014
QAe5000
RO
Z
MP
Z
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Accomplishments
• We have assembled a unique collection of data from our partner HESS
• We have complete data base of all geologic data, well logs, and petrophysical measurements in PETRA.
• We have evaluated several upscaling approaches for permeability
• WE have completed preliminary study of diagenesis and have initiated CLT, SEM and isotopic studies
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Synergy Opportunities
– Our study will provide the first detailed publically
available study of a ROZ….. We are reaching
out to other projects as our data becomes
cleared for release by Hess.
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Summary
– Key Findings
We are modifying published facies classification
scheme for the San Andres
Upscaling previously used for these type of
reservoirs is defective… new approaches offer
significant benefits in more realistic flow simulation
There is extensive evidence of H2S migration
apparently between the ROZ and the overlying
main pay zone reservoir. 35
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Summary
– Lessons Learned
Sulfur isotopes of pyrite, anhydrite, produced
water, and oil will likely be needed to resolve
origin of pyrite along fluid pathways in MPZ and
test connection to large scale anhydrite dissolution
in ROZ
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Summary
– Future Plans
We plan to:
(1) Complete geologic logging and facies analysis
(2) Apply new upscaling to Petrel reservoir model
(3) Complete analysis of MCIP and CT data
(4) Carry out electric resistivity and NMR
measurements on selected perm plugs.
(5) Carry of chemistry and isotopic studies of fluids
(6) Initiate simulation modeling
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Appendix
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Organization Chart
Project Director
Ian Duncan
Task 1
Management
Task 2 through 6
Task Leader/Back-up
Duncan/Ambrose
Task Leader/Back-up
Duncan/Ambrose
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Gantt Chart
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Yr1 Q1 Yr1 Q2 Yr1 Q3 Yr1 Q4 Yr2 Q1 Yr2 Q2 Yr2 Q3 Yr2 Q4 Yr3 Q1 Yr3 Q2 Yr3
Q3
Yr3
Q4
2 X X X X X X X X X X D7 X
2.1 x x X D3 x x x x x
2.2 x x x x X D11 x x
2.3 x x x x x x x
2.4 x x x x X D8
2.5 x x x x x x X D9
3 X X X X D4
4 X X X X X X D5 X X D6 X X
4.1 x x x
4.2 x x x x x
5 X X X X X X X X X X
D10
6 X X X
D12
X X X X
D13
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Bibliography
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