Articles

(Journal of Petroleum Technology, February 2010)
The latest issue of JPT, the Journal of Petroleum Technology features an article co-authored by Ingrain's Chief Engineer, Ted Zaleski.  The article discusses how the use of 3D digital imaging and advances in analytical methods are having a significant impact on the technology of perforating, thus playing a vital role in meeting the challenges of maximizing productivity and recovery of wells being drilled today.
 
(The Leading Edge, January 2010)
Stanford University's Jack Dvorkin and Ingrain's Jonas Tolke, Chuck Baldwin, Yaoming Mu, Naum Derzhi, Qian Fang and Avrami Grader discuss the digital experimentation of flow simulations and permeability calculations in the latest issue of The Leading Edge

From Micro to Reservoir Scale: Permeability from Digital Experiments
(The Leading Edge, December 2009)
Stanford University's Jack Dvorkin and Ingrain's Naum Derzhi, Qian Fang, Amos Nur, Boaz Nur, Avrami Grader, Chuck Baldwin, Henrique Tono and Elizabeth Diaz explain how digital rock physics can reliably enhance data obtained from physical laboratories and reduce the number of complicated and costly measurements being used today. 
 
Capturing Digital Rock Properties for Reservoir Modeling (World Oil, October 2009)
The latest issue of World Oil magazine features an Ingrain case study co-authored with Noble Energy.  The case study discusses how comparative analysis shows that a digital and real core compare favorably when digital and real experiments are run.
 
Revolutionizing Core Analysis (GEO ExPro, September 2009)
Houston-based Ingrain uses latest-generation 3D CT (computed tomography) to quickly and accurately determine absolute and relative permeability, resistivity, elastic properties, pore and grain statistics. Results are available in days, they claim, even in ultra-low permeability sandstones, complex carbonates and shales.

Ingrain's digital rock physics lab images the details of rock structure at the pore scale and uses these images to accurately simulate physical experiments in the computer.  Only recently have powerful 3D scanners and computing clusters rendered this concept commercially viable on such complex physical objects as natural sediment. At Ingrain, different properties of rock are measured and interrelated at a varying spatial scales. This is hardly possible in the physical laboratory or in the well, where the scale of measurement is fixed.
 
Digital imaging and computation revolutionised photography by making film cameras obsolete and moving image processing from chemical darkrooms into computers. Ingrain, a Houston-based technology start-up, is using digital imaging and computation to reinvent special core analysis. At Ingrain’s digital rock physics lab, latest-generation CT (computed tomography) scanners capture in 3D the actual fabric of reservoir rock samples – the pore-space and mineral matrix geometry fabric – at resolutions as high as 100 nanometres.
 
Rock physics company expands into Brazil (JPT Online, January 2009)
Houston-based digital rock physics company Ingrain recently announced plans to open a new digital rock physics lab in Rio de Janeiro, Brazil. This lab, the company’s second, will provide advanced three-dimensional (3D) imaging and computational methods to Brazilian clients who want fast and accurate measurement of a range of reservoir rock properties. 
 
New technology continues to amaze  (Hart's E&P, December 2008)
With capital at their disposal, operators and service companies pulled out all the stops in 2008.
 
Finding Huge Potential in Rocks' Tiniest Cracks (The Houston Chronicle, December 2008)
Houston-based Ingrain uses nano-scale imaging technology to rapidly measure the porosity, permeability and fluid flow characteristics of oil and gas shale formations.

(Hart's E&P, November 2008)
Next-generation computed tomography(CT) scanning reveals the actual pore structure of shale reservoirs at the nanometer scale, and breakthrough algorithms compute the physical properties of shale from these 3-D images - all with unprecedented accuracy.
 
A Closer Look  (Oilweek, November 2008)
As earth scientists examine how to produce more oil from discovered resources, nanotechnology could provide insight into reservoir properties.
 
Applying the "New" Math (Nickles New Technology Magazine, October 2008)
A new paradigm for assessing permeability in reservoir rock.
 
Imaging at a Finer Scale (Hart's E&P, October 2008)
A new company is showing its client reservoir rock information at the pore scale.
 
(First Break, September 2008)
Jack Dvorkin, Meghan Armbruster, Chuck Baldwin, Qian Fang, Naum Derzhi, Carmen Gomez, Boaz Nur, Amos Nur and Yaoming Mu propose the novel use of a virtual rock physics laboratory as a pragmatic way to improve the quantifying and understanding rock without damaging the usefulness of rock samples for further experimentation.
 
  (SPE ATCE Show Daily, September 2008)
At this year's SPE Annual Technical Conference and Exhibition, first time attendee Ingrain brings the upstream industry a new paradigm in rock properties measurement that allows operators to create smarter, more efficient field development plans.
 
Quantitative Virtuality! (Oil Information Technology Journal, Jul-Aug 2008)
Ingrain's Jack Dvorkin makes a compelling case for a new kind of special core analysis: combining a state-of-the-art 3-D NanoXCT X-Ray tomographic scanner and high-performance computer modeling.
 
Calculating the Properties of Rock (Digital Energy Journal, Jun-Jul 2008)
New rock physics company Ingrain has developed a new method to calculate rock porosity and permeability by taking a high-resolution scan of small rock sample