Relationships of λρ, µρ, brittleness index, Young's modulus, Poisson's ratio, and high total organic carbon for the Marcellus Shale, Morgantown, West Virginia
- Thomas Wilson (West Virginia University) | Payam Kavousi (West Virginia University) | Timothy Carr (West Virginia University) | Brooke Carney (Northeast Natural Energy LLC) | Natalie Uschner (Schlumberger) | Oluwaseun Magbagbeola (Schlumberger) | Lili Xu (Schlumberger)
- Document ID
- Society of Exploration Geophysicists
- 2017 SEG International Exposition and Annual Meeting, 24-29 September, Houston, Texas
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Exploration Geophysicists
- Unconventional, Interpretation, Reservoir characterization, Microseismic, Fracture stimulation
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Inversion of 3D-3C data yields P- and S-acoustic impedances that can be combined to yield λρ and μρ (e.g. Goodway et al., 1997; Hampson et al., 2005; Russell, 2014; Sayers et al., 2015). λ and μ, Lamè's parameters, represent incompressibility and shear modulus, respectively. Interpretation of λρ-μρ volumes has been used recently to evaluate unconventional oil and gas shale reservoirs (see Alzate, 2012; Alzate and Devegowda, 2013; and Perez and Marfurt, 2014 and 2015). Alzate and Devegowda (2013) use λρ-μρ crossplots to identify organic rich and brittle sweet spots. They also associate lower Young's modulus with more organic rich intervals and lower Poisson's ratio with more brittle intervals.
In this study we compute λρ-μρ from log data for the Middle Devonian Hamilton Group and bounding Tully and Onondaga limestones taken from the vertical pilot well (Figure 1) drilled by Northeast Natural Energy, LLC on their Morgantown, WV well pad. We also compute brittleness using approaches proposed by Greiser and Bray (2007), Jarvie et al. (2007) and Wang and Gale (2009). We then note the results of a stimulation test and consider hydraulic fracture development within the context of these log derived parameters and mechanical properties. The stimulation tests are conducted using a geomechanical model developed from a comprehensive suite of logs collected in the vertical pilot well by Schlumberger (see Wilson et al., 2016).
Results indicate that the TOC (total organic carbon) rich Marcellus Shale is associated with lower Young's modulus, Poisson's ratio and lower values of λρ and μρ. High TOC intervals tend to be more brittle using both the Jarvie et al. (2007) and Wang and Gale (2009) approaches; however, brittle intervals are not confined to TOC rich zones. Model hydraulic fractures are, however, generally confined to TOC rich strata, while microseismic activity associated with shear failure of pre-existing natural fractures during treatment is distributed through the Hamilton Group.
Presentation Date: Tuesday, September 26, 2017
Start Time: 9:45 AM
Location: Exhibit Hall C/D
Presentation Type: POSTER
|File Size||1 MB||Number of Pages||5|