1. International Shale Development Optimization

2. Unconventional Resources Development
Completion Quality
Reservoir Quality

3. Controls for Reservoir Productivity
Defining Reservoir Quality
TOC and maturation
Mineralogy
Pore Pressure
Petrophysics: porosity, saturations, permeability, thickness
Gas in place: adsorbed, interstitial
Defining Completion Quality
Structure: faults, natural fractures, curvature
Hydraulic fracture containment: geomechanical anisotropy, in-situ stress
Rock fracturability: surface area per reservoir volume, texture, complexity
Retention of surface area and fracture conductivity: stress, mechanical properties
Fracturing fluid sensitivity: mineralogy, fluid chemistry
Good Reservoir Quality + Good Completion Quality = Economic Success

4. Shales are Vertically Variable Each Shale is Unique
Woodford
Barnett
Fayetteville
Haynesville
Marcellus
Eagle Ford
Eagle Ford (oil)
Shales are Vertically Variable
Each Shale is Unique

5. Core/Log Petrophysical Analysis
RHOB RHOM
ECS XRD
Sw Porosity
TOC Perm
Gas in Place GR
Res
Porosity
ELAN
250 ft thick organic shale stimulated in a single frac stage. The microseismic results shows that the lower section of the shale was not effectively stimulated. Interestingly, this section has a higher clay volume (high stress). This indicates that organics in this lower section may not be effectively produced.
Effective phi: 4 to 12 pu
TOC: > 2 wt %
Saturations: Sliquid < 45%
Permeability: > 100 nd

6. Shale in Perspective: Permeability
100 nD = D = 1 ten millionth of a Darcy

7. Shale in Perspective: Permeability
100 nD = D = 1 ten millionth of a Darcy
Consequence of Extremely Low Matrix Permeabilities:
Majority of Pressure Drop at Fracture Face
At Initial Reservoir Pressure 10s of meters from fracture for years
Hydraulic Fracturing is a REQUIREMENT
Hydraulic Fracture Complexity can induce a pressure drop from multiple directions
10 ft
10 Year Pressure Profile
Hydraulic Fractures at 250 ft Spacing (400 nd)

8. Shale in Perspective: Large Stimulation Treatments

9. Initial Completion Quality Evaluation:
Vertical Fracture Height Growth
300 m
80 m
250 ft thick organic shale stimulated in a single frac stage. The microseismic results shows that the lower section of the shale was not effectively stimulated. Interestingly, this section has a higher clay volume (high stress). This indicates that organics in this lower section may not be effectively produced.

10. Initial Completion Quality Evaluation:
Vertical Fracture Conductivity
80 m
RA tracer of the same frac job. The high clay volume interval in the middle may be a fracture barrier. Note, the upper perfs and lower perfs were fracced at the same time. Even if the frac grows through the interval it may be a fracture conductivity barrier during production. A horizontal well may not effectively produce gas across this barrier.

11. Completion Quality Variability
Fayetteville Shale Outcrop
Fayetteville shale outcrop showing vertical variability.
Image logs from multiple shale reservoirs showing countless laminations and continuous variability.
Formation Micro-Imaging Logs (FMI)
Reservoir 1
Reservoir 2
Reservoir 3

12. Lateral Heterogeneity – Horizontal Image Logs
Reservoir 1
600 m
Reservoir 2
500 m
Reservoir 3
Same image logs as the previous slides, plus the addition of a LWD GVR. The depiction on the previous slide visually infers that the logs are from vertical pilot holes (note, nothing states this on the slide or in the notes). In reality, all of these images are from laterals. The lateral with the GVR is in zone over much of the wellbore. But the borehole still crossed many beds.
This visually portrays the task we face when trying to correlate beds encountered in laterals with beds from vertical wells. It also visually demonstrates the variability that is solely due to bedding that we will likely see in cores from horizontal wells.
700 m

13. Production Along the Lateral is Not Uniform
Clusters producing no more than 2% of total production
51%
Non-producing clusters
Well 1
54%
14%
31%
Well 2
53%
47%
Well 3
Well 4
18%
37%
This slide shows a snapshot of some of the results of a horizontal shale production log analysis that we have performed. Each graph represents a horizontal well and the bars on the graph denote the percent of flow from a perforation cluster along the lateral.

14. Addressing Variable Completion Quality
Wireline Horizontal Geomechanical Analysis
Quantify lateral stress variation
Indentify stress anisotropy
Group frac stages in “Like Rock”
Perforate similarly stressed rock
Stage 4
Stage 3
Stage 2
Stage 1

15. Addressing Variable Completion Quality
4/22/2017
Addressing Variable Completion Quality
LWD Horizontal Geomechanical Analysis
Gamma Ray
Resistivity
Den /Neu
Porosity
Den Image
Static
Dynamic
GR Image G H I H G F E D C B A
Formation Dips from Images
Planned Trajectory
Actual Trajectory

16. Addressing Variable Completion Quality
4/22/2017
Addressing Variable Completion Quality
Images can Identify Natural Fractures

17. Putting it All Together
4/22/2017
Putting it All Together
Den Image
Spectroscopy
Volumetric
Porosity /
Saturations
TOC
HC in Place
Reservoir, Pay
Reservoir Quality
Completion Quality
Rock Strength
Frac gradient

18. Addressing Variable Completion Quality Eagle Ford Shale Example – Geometrical Staging
SPE134827

19. Addressing Variable Completion Quality Eagle Ford Shale Example – Selective Staging
SPE134827

20. Completion Optimization to Maximize Production
New wells used Reservoir Quality and Completion Quality to optimize completions
33% increase in 3 month average cumulative BOE on new wells compared to offsets
SPE134827

21. 3 Dimensional View of Reservoir

22. Integrating Seismic Attributes with Fracture Geometry
SPE131779
Microseismic event locations along with the azimuth of most negative curvature (arrows) and magnitude of most positive curvature (background color)

23. Coupling Fracture Geometry to Reservoir Simulation
Evaluation of Completion Quality
Unconventional Fracture Geometry Model
shmax
shmin
Eclipse Reservoir Simulation
Petrel platform allows stress heterogeneity integration
A more rigorous numerical fracturing simulator is being developed as well. These simulators require additional information as determined via log, core and/or seismic interpretation, but they allow for integration of all of this data to more accurately predict the fracture network that is created during the stimulation treatments.

24. Eclipse Reservoir Simulation Production History Match
Production Match
Pressure Match

25. Reservoir Exploitation
Completion Quality Optimization
Estimated Ultimate Recoveries
Recovery Factors
Reservoir Development

26. What is the right model for success?
4/22/2017
What is the right model for success?
Model 1…
Model 2…
Minimum data utilized
Accept statistical variation in well performance
Compensate by drilling more wells
Factory approach to drilling and completion
Large footprint – high rates & large fluid volumes
Collect optimum data
Understand the reservoir and completion quality
Reservoir based well placement
Utilize technology to improve drilling & completion efficiency
Reduced equipment footprint and fluid volumes
Good Reservoir Quality + Good Completion Quality = Economic Success 26

27. Thank You Contour map of Completion Quality
Contour map of Reservoir Quality
Good Reservoir Quality + Good Completion Quality = Economic Success