POROLABS has the experience, technology and testing methodology internally to provide clients various core data characteristics with rapid turnaround time. POROLABS is experienced in providing Mercury Injection Capillary Pressure (MICP), Total Organic Carbon (TOC) analysis, and X-Ray Diffraction (XRD) analysis.
POROLABS takes a tailored systematic approach to each of its services in order to optimize and develop the best analytical program based on sample type as well as individual clientele needs. These include, but are not limited to, the following:
MICP analysis provides an accurate and consistent methodology for determining various petrophysical rock properties of a sample.
Yields pore volume distribution of pore sizes between 140 and 0.004 micrometers in diameter. Data provided also includes calculations of:
If requested, Air-Brine and Oil-Brine Pc curves, cumulative intrusion, normalized pore volume distribution, wetting phase saturations and J-Functions can be provided.
Yields the aforementioned intrusion analysis plus extrusion data as the pressure decreases to atmospheric pressure.
The maturity of a rock, as well as its potential to generate oil and/or gas can be evaluated by TOC and Rock Eval pyrolysis or Source Rock (SR) analysis. Various ratios from the data provided by these analyses aid in the interpretation of rock characteristics.
Source rock maturity indicator
S1, S2, S3, Hydrogen Index (HI), Oxygen Index (OI), Production Index (PI), Normalized Oil Contact (NOI), Tmax
These analyses provide clients with the rock properties that influence the effects on reservoir quality, depositional environment, diagenetic history, formation damage prevention and anomalous wireline log response.
Provides documentation of three-dimensional pore geometry and authigenic components.
Provides data used to determine the rock composition and the abundance of clay minerals of a rock sample. Yields weight percent and volume percent of specific minerals present in the rock sample.
Bulk and Detailed Clay Mineralogy
Provides data quickly to identify the characteristics and composition of the rock and confirm the mineralogy of the strata. Measuring the elements within the drill cuttings to determine properties of quartz, limestone, clay and other properties can determine where the laterals are located within the strata, thus identifying what part of the lateral to complete.
Provides a description of lithology, texture, grain size, porosity types, detrital mineralogy, authigenic components, and reservoir quality.
General Thin Section Description: Qualitative description of lithology, texture, grain size, detrital mineralogy, authegenic components, porosity types, reservoir quaility, formation damage. Two Photomicrographs.
Detailed Thin Section Composition Analysis: Description of lithology, texture, grain size, reservoir quality,formation damage. Modal analysis/point count (250 pts.) gives quantitative detrital mineraology, authegenic components, and porosity types. Two Photomicrographs.