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Pennsylvanian Carbonate Reef Pennsylvanian Carbonate Reef Pennsylvanian Carbonate Reef COCOCO222 Sequestration, West TexasSequestration, West TexasSequestration, West Texas
DOE Southwest Partnership Pilot at SACROC and Claytonville oil field sites
Comparison & contrast between a 30 year old and a new injection site
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AcknowledgementsAcknowledgementsAcknowledgements
Special Acknowledgement to Industry Sponsor Kinder Morgan
Authors; Mark H. Holtz, Vanessa Núñez López, Rebecca C. SmithThe University of Texas, Austin
Bureau of Economic Geology
Subsurface Site CharacterizationWork Flow
Delineate Reservoir ArchitectureDelineate Reservoir Architecture
Ascertain Regional Geological SettingAscertain Regional Geological Setting
Determine Fluid & Rock-fluid PropertiesDetermine Fluid & Rock-fluid Properties
Construct Subsurface ModelConstruct Subsurface Model
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West Texas Pennsylvanian Carbonate Reef Stratigraphic Setting
Reservoirs produce from Canyon- Middle Cisco age (290-307 Ma) platform and slope carbonates
PER
MIA
N
StrawnCanyonCiscoRegional Wolfcamp shale
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M i d l a n d B a s i n
C laytonville
Pennsylvanian reef reservoirsModified from Galloway, et al. (1983)
SACROC
LYNN GARZA KENT STONEWALL
DAWSON
TERRY HASKELL
KNOX
BORDEN SCURRY FISHER JONES
TAYLORNOLANMITCHELLHOWARD
MARTIN
COKE0 20 mi
0 30 km
QAd4569x
SACROC & Claytonville Location and Regional Geology
Aggradationalisolated platform setting
ProgradationalRamp setting
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Eastern Shelf Stratigraphy
Whitehorse/Pease River
Clear Fork Group
Wichita-Albany Group
Cisco Group
Canyon Group Strawn Group
Paleozoic rocks undifferentiated
Ogallala Fm.Dockum Fm.
0 25Miles
Seymour Fm.
S.L.
12345
123
X 1000 ftFisher
Dickens
Haskell
Crosby
Kent
Scurry
Stonewall
Claytonville & SACROCProduction zones
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Pennsylvanian Reef CO2Sequestration Potential
99
58
0102030405060708090
100
CO
2 S
eque
stra
tion
Cap
aciit
y (M
illio
n To
ns)
HORSESHOE ATOLL EASTERN SHELFREEFS
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Pennsylvanian Reef CO2 Miscible EOR Resource Potential
143
123
110
115
120
125
130
135
140
145
EO
R P
oten
tial (
MM
STB
)
HORSESHOE ATOLL EASTERN SHELFREEFS
Bureau of Economic Geology
Subsurface Site CharacterizationWork Flow
Delineate Reservoir ArchitectureDelineate Reservoir Architecture
Ascertain Regional Geological SettingAscertain Regional Geological Setting
Determine Fluid & Rock-fluid PropertiesDetermine Fluid & Rock-fluid Properties
Construct Subsurface ModelConstruct Subsurface Model
Bureau of Economic Geology
Claytonville Canyon Lime Type Log
Top of reservoir
Well 22-3
Gamma rayNeutron
0 150
0.4 0
Cor
ed in
terv
al
Core porosity 00.1
Wolfcamp shale
Canyon carbonate reservoir
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0 5,000 ft
N
Originaloil-watercontact
(-3670 ft)
>3800
3800-3600
3400-3600
3200-3400
3000-3200
<3000
Subsea depth totop of reservoir
(ft)
Water injection well
QAd4253x
Claytonville Top of Structure
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Lower reservoir composed of
shoaling upward cycles
Cycle TopBrecciaGrainstoneSkeletal pkstCrinoid wkstMudstone
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Fractured MudstoneWebb # 35,687b ft
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CrinoidWackystone
Webb # 35,684 ft
Bureau of Economic GeologyGrainstoneWebb # 35,778 ft
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BrecciaWebb # 35,726b ft
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BrecciaWebb # 25,448 ft
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Large Vugs
Webb #25,448a
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Subsurface Site CharacterizationWork Flow
Delineate Reservoir ArchitectureDelineate Reservoir Architecture
Ascertain Regional Geological SettingAscertain Regional Geological Setting
Determine Fluid & Rock-fluid PropertiesDetermine Fluid & Rock-fluid Properties
Construct Subsurface ModelConstruct Subsurface Model
Bureau of Economic Geology
Tasks For Establishing Fluid Flow Trends in a Reservoir
1. Ascertain the initial fluid Properties1. Reservoirs fluid properties2. Overlying water properties
2. Rock-fluid petrophysical properties3. Generate a production time series analysis4. Assess well test data5. Determine flow directions of injected fluids
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Reservoir Fluid Characteristics
• Initial GOR: 1200 scf/STB• Oil API gravity: 42• Original oil formation volume factor: 1.510• Bubble point pressure (psi): 1850• Oil viscosity @ Pb (cp): 0.35• Sulfur content of oil: 0.32• Gas gravity: 1.13• Connate water salinity (PPM): 59,000
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Groundwater Characterization
• Compile existing data from eight county study area • Identify regional variability of existing analyses, • Additional groundwater sampling (Install 4 new water wells in Claytonville)
major ion, total organic carbon, stable isotopes of hydrogen (D/H), oxygen (18O/16O), and
carbon (13C/12C);Sr isotopes (reservoir brines and shallow groundwater)pH, temperature, and alkalinity field measurements,
• Geochemical equilibrium and flowpath modeling to identify groundwater mixing.
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Major and Minor Aquifers and Sample Wells
Claytonville
SACROC
Dockum
Ogallala
Edwards Plateau
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Mapping water chemistry with stiff diagrams
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Tasks For Establishing Fluid Flow Trends in a Reservoir
1.1.1. Ascertain the initial fluid PropertiesAscertain the initial fluid PropertiesAscertain the initial fluid Properties1.1.1. Reservoirs fluid propertiesReservoirs fluid propertiesReservoirs fluid properties2.2.2. Overlying water propertiesOverlying water propertiesOverlying water properties
2. Rock-fluid petrophysical properties3.3.3. Generate a production time series analysisGenerate a production time series analysisGenerate a production time series analysis4.4.4. Assess well test dataAssess well test dataAssess well test data5.5.5. Determine flow directions of injected fluidsDetermine flow directions of injected fluidsDetermine flow directions of injected fluids
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Porosity-Permeability CharacterCore Data Well 22-3
Webb # 3 5682 -5876
0.01
0.1
1
10
100
0 0.01 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.09 0.1
Porosity (fraction)
Perm
eabi
lity
(md)
Average0.034
Permeability Geometric Average0.283 md
Puzzle is in the petrophysics ?
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Transform derived porosity
Top of reservoir
Core Transform Log
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Summary• The SACROC/Claytonville Southwest Carbon
Phase 2 project is being implemented in a Carbonate Pennsylvanian Reef setting
• Project is a comparison/contrast between a 30 year old injection site and a new injection site
• Progress to date– 3 D seismic and VSP– New well drilled, cored and wireline logs obtained– Subsurface characterization in progress
• CO2 injection scheduled for spring 2007
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Thank you