Using Seismic Data For Intelligent Well Placement - Halliburton.pdf

Beyond Factory Drilling: Using Seismic Data for Intelligent Well Placement

Nick Boyd Geophysicist Halliburton Consulting

Halliburton Shale Characterization Objectives  Evaluate specific specific behavior that impact the system behavior

sweetspots  Identify potential locations of sweetspots  Evaluate geochemical and geomechanical geomechanical parameters parameters  Determine wellbore wellboregeometries geometries  Evaluate completion and stimulation strategies completion and stimulation strategies

wellperformance performance  Predict and evaluate well  Optimize programs Optimizewellbore wellbore programs

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Eagle Ford 3-D Seismic Acquisition– South Texas PATRON GRANDE 3-D FRIO COUNTY

DIMMIT

CATARINA 3D 261 SQ. MILES

EAGLE GRANDE 3D 902 SQ. MILES

REPUBLIC 3D LA 158 SQ. MILES

INTREPID 3D 394 SQ. MILES

McMULLEN COUNTY

Group Interval:

220 ft.

Source Interval:

220 ft. (source line orthogonal to receiver lines)

Receiver Line Spacing:

1,540 ft.

Source Line Spacing:

1,100 ft.

Geophone:

Basic Patch:

SALLE PATRON 3D 928 SQ. MILES

HAWK FIELD3D 276 SQ. MILES

LIVE OAK COUNTY

Sources:

3 per station 2410Hz, lines x 180 receivers Vibroseis, slip sweep technique, 3 vibs per (4,320 channels) fleet, 1 sweep x 36 seconds, 6 second

Maximum Far Offset: Basic Patch: Maximum Far Surface Square Miles Offset Inline: Bin Size:

WEBB COUNTY

(approx):

Maximum Far OffsetFar Crossline: Maximum Offset Inline: Maximum Far Offset:

listen time, minimum slip time 26 seconds

26,929 ft.

24 lines x 180 receivers (4,320 channels) 110 ft. by 110 19,690 ft.ft. 781

18,370 ft.

26,929 ft. 19,690 ft.

Maximum Far Offset Crossline:

Fold:

18,370 ft. 216 all offsets (18 in-line x 12 cross-line)216 70-74 at 0-12,500 all offsetsfold (18 in-line x 12 cross-line) Fold: 70-74 fold at 0-12,500 ft. offset ft. offset 158-165 fold at 0-18,750 158-165 fold at 0-18,750 ft. offset ft. offset 6 seconds Record Length: Sample Rate:

2 ms

3,300 sq miles 3-D Seismic in the Eagle Ford © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Moving Beyond Classic Seismic Interpretations Interface boundaries and layer property analysis Interpretation from reflections

Interpretation Earth Model

Dry holes not because of where reservoir is.

Pre-stack data gives reservoir information

Thin Section Dry because of what reservoir is.

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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3D Seismic Delivers: PostStack Interpretation  Interface Properties: Reflections for structure/stratigraphy

PreStack Interpretation  Isotropic Layer Properties: – Prestack Inversion for Lithology, Porosity, Pore Fluid, Young’s Modulus, Poisson’s Ratio  Anisotropic Layer Properties: – Long offset acquisition & VTI for Vertical Stress & Pore Pressure – Wide Az – Full Az acquisition indicate Fast & Slow velocity & HTI for fracture mapping/horizontal stress

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Sources of Anisotropic Rock Media Properties Formation Anisotropy Classification Stress-Induced

Intrinsic

Intrinsic

V (r, ) Shale, Bedding - VTI V (r, )

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Fractures - HTI V ()

Anisotropy Observed at All Length Scales

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Sonic Logs Seismic VTI Anisotropy Viewed by Long-Offset DTC DTS Fast DTS Slow

Buller et al (2010) SPE 132990 © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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HTI Anisotropy– Full Azimuth 3-D Seismic Vs V

V

Vf Vs

No Fractures = Isotropic

Dominant Fractures In One Direction = HTI Anomaly

Full Azimuth

Narrow Azimuth © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

Fractures but no Dominant Direction = Velocity Anomaly

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HTI, H , Microseismic Events in the Barnett

Rich & Ammerman (2010) SPE 131779 © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Total Reservoir Characterization

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Reservoir Trending: Dipole Sonic Data and Cross Plot Case Study: One formation, three wells 1.6

Well 3

Mu Rho

1. 8

16000

Well 1

2.0

Well 2

1400 0 1200 0 Constant S Impedance (ft/s*g/cc

Fluid

)

Lambda Rho © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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(ft/s*g/cc )

1.6 1.6 1.6

1.8 1.8 1.8 1.8

Mu-Rho Mu-Rho Mu-Rho (GPa*g/cc) (GPa*g/cc) (GPa*g/cc)

2.0 2.0 2.0 8000 8000 8000 8000

2.2 2.2 2.2 2.2

7000 kPa s/m 7000 kPa s/m 7000 kPa s/m

uK uK

6000 6000 6000 6000 5000 kPa s/m 5000 kPa s/m 5000 kPa s/m 5000 kPa s/m

Sh 1 Lambda-Rho (GPa*g/cc) Lambda-Rho (GPa*g/cc) Lambda-Rho (GPa*g/cc) Lambda-Rho (GPa*g/cc) © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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upper K Shale 1 Cretaceou s Shale 2

Rock Physics Links Well Bore and Seismic 1.8

2.0 2.2

200000 kg/m2s

400000

150000

150000

300000 kg/m2s

200000

Lambda Rho (GPa*kg/m3) Boyd et al (2010) © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Gamma Ray

Mu Rho (GPa*kg/m3)

1.6

Reservoir Lithology

Vp/Vs 1.8

1.6

M1

M1- 8 ms.

Boyd et al (2010) © 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Brittleness

Intelligent Wells: Place the Wellbore in the Optimal Location & Orientation

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Brittleness

Intelligent Wells: Stimulating the Right Rocks

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Intelligent Wells: Developing and Optimizing Assets

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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Seismic 3D Landmark

Seismic and Microseismic Landmark and Pinnacle

Seismic Landmark

Shale Core

CONTINUAL VALIDATION OVER ASSET LIFE

ShaleXpert® Halliburton Well Planning Halliburton

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

Microseismic Pinnacle

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QuickLook® Halliburton

Thank You. Questions?

© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

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