Variations in Multiscale (nano to mm) Porosity in the Eagle Ford Shale as a Function of Maturity through the Oil Window
Abstract
Porosity and permeability are key variables that link the thermal-hydrologic, geomechanical and geochemical behavior in rock systems and are thus important input parameters for transport models. Recent neutron scattering studies have indicated that the scales of pore sizes in rocks extend over many orders of magnitude from nanometer pores with huge amounts of total surface area to large open fracture systems (multiscale porosity, cf. Anovitz et al., 2009, 2011, 2013a,b). However, despite a considerable amount of effort combining conventional rock petrophysics with more sophisticated neutron scattering and electron microscopy studies, the quantitative nature of this porosity in tight gas shales, especially at smaller scales and over larger rock volumes, remains largely unknown (Clarkson, 2011). We lack a quantitative understanding of the multiscale porosity regime (i.e., pore size, shape, and volume, pore size distribution, pore connectivity, pore wall roughness) in rocks. Nor is it understood how porosity is affected by regional variation, thermal changes across the oil window, and, most critically, hydraulic fracturing operations. In order to begin to provide a quantitative understanding of porosity at nanometer to core scales in these shale formations and how it relates to gas storage and recovery we have used a combination of small and ultrasmall angle neutron scattering measurments made on the GP-SANS instrument at ORNL/HFIR, and the NG3-SANS and BT5-USANS instruments and NIST/NCNR, with SEM/BSE and X-ray Computed Tomographic imaging to analyze the pore structure of both clay and carbonate-rich samples of the Eagle Ford Shale. The Eagle Ford Shale is a late Cretaceous unit underlying much of southeast Texas and probably adjacent sections of Mexico. It outcrops in an arc from north of Austin, through San Antonio and then west towards Kinney County. It is hydrocarbon rich, and buried portions straddle the oil window. The Eagle Ford is currently one of the most actively drilled oil and gas targets in the US. The first successful horizontal well was drilled in 2008, and 2522 permits were recorded (Texas railroad commission) by Sept 1, 2011. While the oil and gas reserves in the Eagle Ford have been known since the 1970's, prior to the invention of horizontal drilling/hydraulic fracturing it was not considered economic. Several important trends in the rock pore structure have been identified using our approach. Pore distributions are clearly fractal but, as was observed for the St. Peter sandstone (Anovitz et al., 2013a), are composed of several size distributions. Initial porosity is strongly anisotropic, as expected for shales. However, this decreases for shales, and disappears for carbonates with maturity. In both cases significant reduction occurs in total porosity, with most of the change coming at the finest scales (< ~ 10 nm), and an observable decrease at intermediate scales (near 100 nm) Research sponsored by the Division of Chemical Sciences, Geosciences, and Biosciences, Office of Basic Energy Sciences, U.S. Department of Energy, and as part of the Center for Nanoscale Control of Geologic CO2, an Energy Frontier Research Center funded by the U.S. Department of Energy, Office of Science under U.S. Dept. of Energy (DOE) contract DE-AC02-05CH11231.
- Publication:
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AGU Fall Meeting Abstracts
- Pub Date:
- December 2013
- Bibcode:
- 2013AGUFM.H33L..05A
- Keywords:
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- 1859 HYDROLOGY Rocks: physical properties;
- 4440 NONLINEAR GEOPHYSICS Fractals and multifractals;
- 4435 NONLINEAR GEOPHYSICS Emergent phenomena