Shale Services

Digital Rock Analysis for Shale Plays: From Whole Core to Pore Space

In shale, the understanding of the distribution within the organic and inorganic pore networks, their respective connectivity, wettability, and pore geometry are key factors of hydrocarbon recovery. Ingrain’s services enable our clients to unravel these properties for improved understanding of reservoir hydrocarbon storage.


We’ve developed a multi-scale workflow that begins with the whole core (CoreHD®) and systematically classifies the rock to ensure our work at each sampling scale is representative of the reservoir rock types we want to characterize.

  1. For shales, the nanometer scale tells us about the matrix and pore system and is the target for obtaining rock property data.

  2. We use systematic selection techniques to ensure representative rock samples, including whole core facies analysis, plug CT heterogeneity evaluation, and pore correlation statistics.  

  3. Once we are confident in our representative samples, we use DRP to obtain rock property data such as porosity, permeability, TOC, porosity associated with organic matter (HC filled porosity), and conversion ratio.

  4. We select and analyze sufficient number of samples to establish physical and empirical trends (usually 10-15 samples per facies).


CoreHD®: CT Imaging of Whole Core

CoreHD® is Ingrain's breakthrough technology platform for high-definition, dual-energy CT imaging and logging of whole core.
  • Characterize rock types and flow units
  • Quickly optimize the number and location of core plugs for advanced rock properties analysis


Click here to download our CoreHD® Suite Product Quick Guide.


ReconHD®: Drilling Cuttings 

Ingrain’s ReconHD® offers elemental, mineralogical, and geochemical from drilling cuttings in log format.  These quantitative measurements help discriminate lithology, rock facies, reservoir quality, and depositional sequences, and set the foundation for pore system property determination from ZoneID®.

  • Validate target zone

  • Confirm containment

  • Make well to well comparisons


ZoneID®: Pore System Properties from SEM

Identify target zones with ZoneID®: Plug to pore scale evaluation targeted to quickly identify shale rock characteristics from micro-CT, SEM, and mineralogical analysis.

Ingrain’s offering provides the best quality image available in conjunction with a quantitative understanding of the different porosity types. Volume fractions of total porosity, intergranular porosity and organic matter porosity are computed for each 2D SEM image at the resolution required to characterize your rock. 

 Click here to download our fact sheet. 


Three-dimensional computation of permeability, porosity, and organic material from computations on FIB-SEM.

Ingrain’s PoreHD® improves the understanding of the pore and matrix through state of the art imaging in 3D, and quantitative analysis such as porosity - total, connected and isolated, porosity associated with organic matter (PAOM), and permeability – vertical and horizontal. 

This data will allow the client to better understand the relationships between porosity and permeability for each of the primary producing facies which is an important component for reservoir characterization. 

Click here to download our ZoneID® and PoreHD® Suite Product Quick Guide. 


Ingrain has experience with the following shale plays:

  • Bakken
  • Baltic Shale in Poland
  • Barnett
  • Collingwood
  • Duvernay
  • Eagle Ford
  • Haynesville
  • Horn River
  • Marcellus
  • Montney
  • New Albany
  • Niobrara
  • Saudi Arabia shales
  • Tunisia shale
  • Utica
  • Wolfcamp
  • Woodford


 Check our latest upscaling approch with FaciesML™ and FabricsML™

sololink.png Download literature related to Ingrain's work in shale:

Comparative Core Analysis from a Wolfcamp Formation Well, a Case Study

Analysis of New Production Targets in the Springer Shale within the South Central Oklahoma Oil Province (SCOOP) Utilizing the Latest Digital Rock Techniques

Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Analysis

Applying Digital Rock Characterization to a New Anadarko Basin Shale Play

Digital Rock Analysis and Petrophysical Integration for Improved Characterization in the Wolfcamp Formation

Quantifying Variability of Reservoir Properties from a Wolfcamp Formation

Eagle Ford Lateral Wellbore Analysis Using Drill Cuttings

2014 Digital Rock Physics for Shale Plays - trifold brochure

Shale Reservoir Evaluation Improved by Dual-Energy X-Ray CT Imaging, Nov 2012

Digital Rock Physics Provides New Insight into Shale Reservoir Quality, Aug 2011

Eagle Ford Shale Reservoir Properties from Digital Rock Physics - First Break, June 2011

Digital Rock Physics Provide Critical Insights to Characterize Eagle Ford, Feb 2011

Technology Reveals "Inevitable Surprises" in Shale Plays, Nov 2010