development of a geostatic model for a geoscience field
TRANSCRIPT
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Development of a geostatic model for a geoscience field research station in Alberta
Jessica Dongas (CMC, CREWES, U of C)Dr. Don Lawton (CMC, CREWES, U of C)
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Outline
• Introduction• Resources• 5 x 5 km Property Model• 4 x 5 km Geophysical Model• Conclusions & Future work• Acknowlegdments
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Location
Newell County, AB
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Objective
Primary Target: 290‐300 m
Secondary Target: 480 m
~1000 tons/yr CO2
Test limits of current MMV technology (CMC)
Develop new MMV technology for fluid monitoring (CMC)
Site used to improve and enhance 4‐D seismology (CREWES) for fluid containment and
conformance (CMC)
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Resources• Data Suite (IHS Energy)
– 191 wells with digital LAS files (>10 km radius)– FRS (5 km x 5 km) = 21 wells– Limited core data– Deviation surveys and locations– Well tops– Static water levels – 3 m below surface
• Software– Schlumberger Canada Ltd.
• Petrel™ E&P Software Platform 2014.1– IHS Energy Canada Ltd.
• Accumap® and Acculogs® 2013– MS Office 2012
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Data Coverage
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Stratigraphic Column
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5 km x 5 km Property Model• Vertical pillar gridding• Orientation N‐S (in‐line with GW flow)
Defined Grid Volume: 200 x 200 x 922 (nI x nJ x nGrid Layers)• Total #3D cells: 36 million• Total # faults: 0• Horizons honour surfaces
– Surface generation via interpolation – honours well tops
Layering of Cells• Reference surface• Zone division based on cell thickness
– Seal and Target intervals = 0.5 m– Non‐important intervals = 5 m
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Layered Intervals
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Property Calculations
• Well Log Calculator
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γ1
• Property Calculator– Plotted and E from core data– Use E in equation of best fit to calculate
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BBRS Core Data
0.1
1
10
100
1000
0.1 0.12 0.14 0.16 0.18 0.2 0.22 0.24 0.26 0.28 0.3
(M
ax)
(%)
Only two wells – within greater 10 km outside FRS
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Medicine Hat Member Core Data
0.01
0.10
1.000.060 0.070 0.080 0.090 0.100 0.110 0.120 0.130
(M
ax)
(%)
Only one well – within greater 10 km outside FRS
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Log Cut‐offs for VSH and CoalFacies Log Cut‐offCoal RHOB<2; DT>130; PHI_E>0.26; PHIE_E=0.03
Shale GR>95
Silty‐Sand 50<GR<95Sand GR<50
GR, VSH, PEF DT E, TOT, N, FaciesRes
BBRS
Foremost F
ormation
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Petrophysical Modeling
• Gaussian random function simulation algorithm– Conditional Simulation = kriging + unconditional simulation– Parallelized = fast computation time– Models expected variability and distribution in input data
– Uses upscaled well logs (averaged log in 0.5 m or 5 m cell)– Uses variogram settings specified to each zone
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Populated E 5 km x 5 km model
E (m3/m3)
1 km
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P10/50/90 Framework• Conservative/Typical/Optimistic values• Both E and were modeled: 40 iterations
0
0.5
1
1.5
2
2.5
3
3.5
4
4.5
6.85E+05 7.45E+05 8.05E+05 8.65E+05
Freq
uency
Total Pore Volume
Pore Volume 1 Km Clip
BBRS (Primary Injection)
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P10/50/90 Framework for BBRS
0.0%
20.0%
40.0%
60.0%
80.0%
100.0%
120.0%
6.87E+05 7.37E+05 7.87E+05 8.37E+05
Percentage
Total Pore Volume
Total Pore Volume
P10
P50
P90
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4 km x 5 km Geophysical Model• Well‐ties & Synthetic Seismograms
– 8 Well‐ties to two 3D seismic reflection volumes• ‘97 Vintage 3D/1C – Cenovus Energy• ‘14 May 3D/3C – CMC
• Replacement velocity: 2600 m/s• SRD: 800 m• NO checkshot data available – TDR developed on DT
• Wavelet– Zero‐Phase Ormsby
• (15/20‐75/95)– Length: 200 ms– Sample Rate: 2 ms
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Synthetic Seismogram at 7‐22
DT, RHOB
Reflection Coefficients
May 2014 3‐D/3‐C Seismic Data
Synthetic Seismogram
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Five tied wells to ‘97 3D Vintage
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BBRSPakowkiMilk RiverColorado
Medicine Hat
Base Medicine Hat
Second White Specks
Base Fish ScalesBow IslandJoli FouMannville
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Depth Conversion ‐ Velocity Modeling
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2213 m/s
2195 m/s2628 m/s
3252 m/s
2965 m/s
3255m/s
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Model Update• Weighted 75% depth‐converted seismic horizons and 25% well‐top interpretation
• 1 post‐processing smoothing iteration
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‘97 3D/1C‘14 3D/3C
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Model Update
2310 km x 10 km
5 km x 5 km Property Model
4 km x 5 km Geophysical Model
1 km x 1 km FRS
7‐22 WellTime Surfaces
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1 km x 1 km Integrated FRS Model
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(mD)
1 km x 1 km FRS
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Conclusions
• Developed 5 x 5 km property and 4 x 5 km geophysical model– From existing well, core, and seismic data
• Built‐in workflows and mechanics– Can be easily updated
• P10/50/90 statistics for E and – Both primary and secondary injection intervals
• BBRS: E: 0‐27% : 0‐360 mD• Medicine Hat Mbr: E: 0‐18% : 0‐1 mD
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Ongoing & Future Work
• Identify sandstone zones in Medicine Hat Mbrusing shallow resistivity log
• Simulation of fluid injection• Study behaviour of P‐ & S‐waves on intervals of injection
• Update model with new logs and core from drilled well
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Acknowledgements• Carbon Management Canada• CREWES Sponsors• NSERC through the grant CRDPJ 379744‐08• Wade Zaluski (Schlumberger Ltd. – Senior Geologist)• Si‐Yong (Schlumberger Ltd. – Reservoir Engineer)• Valerie Smith (Schlumberger Ltd. – Reservoir Geophysicist)
• Dr. Per Pedersen • Dr. Helen Isaac• IHS Energy Canada• Schlumberger Ltd. Canada
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