US Pat. No. 9,372,162

CHARACTERIZATION OF SUBTERRANEAN FORMATION PROPERTIES DERIVED FROM QUANTITATIVE X-RAY CT SCANS OF DRILL CUTTINGS

Ingrain, Inc., Houston, ...

1. A method to characterize subterranean formations, comprising:
a) extracting drill cuttings from a used drilling fluid at the Earth's surface, wherein the drilling fluid transports the
drill cuttings to the Earth's surface after use of the drilling fluid in a drilling of a wellbore in a subterranean reservoir;

b) grouping the drill cuttings into a group of cuttings based on a time of arrival of the drill cuttings at the Earth's surface;
c) repeating steps a) and b) at least once to provide a plurality of groups of drill cuttings that arrive sequentially at
different recorded times at the Earth's surface, wherein the plurality of groups of drill cuttings are placed in separate
respective containers in a sequential arrangement thereof, wherein different containers are used to store different groups
of drill cuttings having different times of arrival;

d) measuring a bulk density of at least one of the plurality of groups of drill cuttings of c) to provide a measured bulk
density;

e) performing a multi-energy X-ray CT scan of the at least one group of drill cuttings of d) to generate digital images of
the drill cuttings of the group of drill cuttings;

f) estimating an estimated bulk density and effective atomic number as data pairs for each of the cuttings of the at least
one group of cuttings scanned in e), wherein the estimating of the estimated bulk density further comprises using the measured
bulk density measured in step d) in calibrating and adjusting estimated density values determined for the cuttings of the
at least one group of cuttings scanned in e);

g) assembling a reconstituted core using at least of a portion of the at least one group of drill cuttings; and
h) determining at least one rock or formation parameter associated with a subterranean location in the subterranean reservoir
using the reconstituted core.

US Pat. No. 9,127,529

PROCESS AND SYSTEM FOR PREPARATION OF X-RAY SCANNABLE SAMPLE-EMBEDDED SLIVER FOR CHARACTERIZATION OF ROCK AND OTHER SAMPLES

Ingrain, Inc., Houston, ...

1. A method for preparing and utilizing a sample-embedded sliver for x-ray scanning and evaluation which comprises steps of:
(i) extracting a plug from a core obtained from drilling a wellbore;
(ii) optionally performing a single energy scan on the plug for sample selection;
(iii) cutting a selected sample having opposite sides from the plug;
(iv) positioning the sample within a casting container;
(v) introducing flowable encapsulant into the casting container to encapsulate at least a peripheral edge that extends around
the sample and between the opposite sides thereof;

(vi) hardening the encapsulant to form a sample-embedded intermediate carrier which is removable from the container;
(vii) machining a side of the sample-embedded intermediate carrier to expose a flat face of the sample to produce a first
exposed face;

(viii) machining to produce a second exposed face on an opposite side of the sample to the first exposed face, wherein the
first and second faces are parallel to each other and spaced in part by a thickness of the sample, to provide an x-ray scannable
discrete sliver comprising a thin planar sliver sample encapsulated at a peripheral edge thereof within surrounding encapsulant
in thin layer form which structurally stabilizes the resulting sliver; and

(ix) capturing at least one digital image of the sliver sample using x-ray scanning.

US Pat. No. 9,080,946

DIGITAL ROCK ANALYSIS SYSTEMS AND METHODS WITH MULTIPHASE FLOW REV DETERMINATION

Ingrain, Inc., Houston, ...

1. A digital rock analysis method that comprises:
deriving from a pore-matrix model at least one pore structure parameter;
determining a distribution of multiple phases within pores of the pore-matrix model;
based on said distribution, partitioning the pore-matrix model into multiple phase-matrix models;
deriving said at least one pore structure parameter from each of the phase-matrix models; and
producing a representation of the at least one pore structure parameter's dependence on said distribution.

US Pat. No. 9,064,328

DUAL IMAGE METHOD AND SYSTEM FOR GENERATING A MULTI-DIMENSIONAL IMAGE OF A SAMPLE

Ingrain, Inc., Houston, ...

1. A method for generating a multi-dimensional image of a sample, comprising:
capturing a first two-dimensional substrate image of a surface region of the sample with a first image capturing modality,
wherein the first two-dimensional substrate image is a surface electron two-dimensional substrate image and wherein locations
of at least one material at the surface region are captured;

capturing a second two-dimensional substrate image of the surface region with a second image capturing modality which is different
from the first image capturing modality, wherein the second image capturing modality provides greater accuracy with respect
to locations of at least one material at the surface region than the first image capturing modality;

spatially aligning the first two-dimensional substrate image based on the second two-dimensional substrate image;
generating a first corrected two-dimensional substrate image based at least in part on the locations of the at least one material
in the second two-dimensional substrate image, wherein said generating comprises determining a porosity of the substrate based
on the surface electron two-dimensional substrate image corrected by comparison to the second two-dimensional substrate image.

US Pat. No. 9,140,117

METHOD FOR EVALUATING RELATIVE PERMEABILITY FOR FRACTIONAL MULTI-PHASE, MULTI-COMPONENT FLUID FLOW THROUGH POROUS MEDIA

InGrain, Inc., Houston, ...

1. A method for estimating relative permeability for fractional multi-phase, multi-component fluid flow through a porous medium
comprising steps of:
(a) creating a three dimensional digital representation of a porous medium comprising scanning a sample of the porous medium
using a scanning device to make an image of the porous medium and segmenting the image to produce the three dimensional digital
representation of the porous medium;

(b) performing a first or precursor simulation over a first computational domain of the three-dimensional digital representation
of the porous medium, wherein the first computational domain extends from an inlet plane to an outlet plane and a selected
storage plane is located between the inlet and outlet planes, which comprises:

(1) setting the initial condition for the precursor simulation where the initial distribution of the fluid is single or multi-phase
flow within the volume,

(2) defining a nominal pressure at the outlet of the volume,
(3) assessing properties of the wetting fluids and non-wetting fluids,
(4) defining an inlet pressure in order to have a selected flow rate,
(5) simulating injecting of single phase fluid into the inlet plane of the sample towards the storage plane and the outlet
plane,

(6) calculating sets of variables comprising fractional flow rates, pressures, saturations, and velocities of the wetting
and non-wetting phases for all points in the porous medium within the first computational domain for successive time increments,

(7) determining if saturation at the storage plane has changed one of a preselected percentage amounts after the calculating
done at each of the time increments of step (6), and if so, storing index values for the storage plane wherein the stored
index values comprise sets of variables which comprise the saturations, and/or pressures, and/or velocities of the wetting
and/or non-wetting phases of the storage plane measured for the time increment for which the determining is done,

(8) determining after step (7) if saturation in a volume of the porous medium defined by the first computational domain is
at quasi steady state,

(9) repeating steps (5), (6), and (7) for a successive time increment if saturation in the volume is not determined to be
at quasi steady state in step (8) or ending the simulating of step (5) if quasi steady state is determined in step (8), wherein
a last set of stored index values in step (7) are designated final index values;

(c) performing a second simulation over a second computational domain of the three-dimensional digital representation of the
porous medium sample, wherein the second computational domain is defined by said storage plane which represents an inlet plane
for the second computational domain and said outlet plane used in the precursor simulation, which comprises

(i) setting the initial condition for the precursor simulation where the initial distribution of the fluid is single or multi-phase
flow within the volume,

(ii) defining a nominal pressure at the outlet of the volume,
(iii) setting inlet flow conditions of the second simulation from the storage plane of the precursor simulation, wherein a
first plane determines a first fractional flow injection of wetting and non-wetting fluid,

(iv) simulating injecting of dual phase fluids into the inlet plane of the sample of the second simulation towards the outlet
plane, wherein fractions of wetting and non-wetting phases are injected according to the saturation and pressure distribution
values stored from the precursor simulation at the storage plane, beginning with initial index values of zero for the first
couple of fractional flows stored in the precursor simulation,

(v) calculating fractional flow rates, pressures, saturations, and velocities of the wetting and non-wetting phases for all
points in the porous medium within the second computational domain for a time increment during the simulating of step (iv),

(vi) determining after step (v) if quasi steady state is reached,
(vii) repeating steps (v) and (vi) for a successive time increment if quasi steady state is not determined in step (vi),
(viii) storing the fractional flow rates, pressure, and saturations distribution calculated in step (v) if quasi steady state
is determined in step (vi),

(ix) determining if final index values stored for the variables at the storage plane in the precursor simulation have been
reached if quasi steady state is determined in step (vi),

(x) repeating steps (v), (vi), (vii), and (viii) if determined in step (ix) that the final index values stored for the storage
plane in the precursor simulation have not been reached, comprising using inflow conditions for the calculating in step (v)
which correspond to successively stored index values for the variables at the storage plane from the precursor simulation,
and

(xi) calculating relative permeability of at least one of the wetting phase and non-wetting phase if the final index values
stored for the variables at the storage plane in the precursor simulation are determined to have been reached in step (ix).

US Pat. No. 9,183,326

METHOD FOR SIMULATING FRACTIONAL MULTI-PHASE/MULTI-COMPONENT FLOW THROUGH POROUS MEDIA

Ingrain, Inc., Houston, ...

1. A method for simulating fractional flow of wetting fluids and non-wetting fluids through porous medium comprising the steps
of:
a) creating a three dimensional digital representation of a physical sample of a porous medium (Sample) containing a total
volume of fluids comprising wetting fluids and non-wetting fluids, wherein the creating comprises scanning the Sample with
a device producing a three-dimensional (3D) digital representation of porous structure of the Sample,

b) defining a first fraction of the total volume of fluids that comprises the wetting fluids and a second fraction of the
total volume of fluids that comprises the non-wetting fluids,

c) defining a value for a flow rate of the total volume of fluids flowing through the Sample,
d) assessing properties of the wetting fluids and the non-wetting fluids,
e) defining initial conditions for saturation of the wetting fluids (Sw), saturation of the non-wetting fluids (Sn), inlet
pressure of the wetting fluids (Pw) and inlet pressure of the non-wetting fluids (Pn),

f) setting conditions at the inlet face of the Sample wherein non-wetting fluids and wetting fluids enter the pores of the
Sample in separate and distinct areas, and

g) calculating pressures, saturation, and velocity vectors internal to the Sample,
h) calculating flow rates of the non-wetting fluids (Qn) through the Sample, flow rates of the wetting fluids (Qw) through
the Sample, and pressure at the outlet of the Sample,

i) repeating steps a) through h) for a predefined number of time increments, t, and
j) periodically adjusting the inlet pressures Pn and Pw using a feedback control algorithm wherein quasi-steady state values
for Qn and Qw are achieved.

US Pat. No. 9,047,513

METHOD FOR IMPROVING THE ACCURACY OF ROCK PROPERTY VALUES DERIVED FROM DIGITAL IMAGES

Ingrain, Inc., Houston, ...

1. A method for increasing the accuracy of a target property value derived from a digital image representing a material sample,
comprising:
a) obtaining a three-dimensional tomographic digital image of the material sample;
b) generating a preliminary segmented volume corresponding to the material sample by processing the three-dimensional tomographic
digital image through a segmentation process;

c) obtaining a criterion relation developed independently of the preliminary segmented volume as a function of values of criterion
properties related to the target property;

d) creating an adjusted segmented volume through additional revising features to the preliminary segmented volume, comprising:
1) applying a processing step to identify locations for potentially revising features of the preliminary segmented volume;
2) applying revision features to the preliminary segmented volume to create a revised segmented volume;
3) deriving trial values of criteria properties from the revised segmented volume;
4) repeating at least steps 2)-3) on the revised segmented volume until trial values of criterion properties satisfy the criterion
relation; and

e) deriving a final value for the target property from the adjusted segmented volume.

US Pat. No. 9,507,047

METHOD AND SYSTEM FOR INTEGRATING LOGGING TOOL DATA AND DIGITAL ROCK PHYSICS TO ESTIMATE ROCK FORMATION PROPERTIES

Ingrain, Inc., Houston, ...

1. A method for making estimates of subterranean rock properties, comprising:
a) positioning a logging tool inside a well bore,
c) measuring in situ well properties in the well interval in the well using the logging tool,
d) estimating rock properties in the well for a location of the logging tool in the well interval using the measured in situ
well properties,

e) retrieving at least one rock sample from the well interval in the well,
f) preparing said at least one rock sample for digital rock physics analysis,
g) scanning the at least one rock sample to produce a digital image of said rock sample,
h) segmenting said digital image of said rock sample to define pores and grains in said digital image,
i) adjusting said digital image to represent said rock properties at in-situ conditions using said well properties,
j) calculating rock properties from said adjusted digital image of said rock sample using said in situ fluid properties,
k) comparing said rock properties at the well interval where the logging tool was positioned and said rock properties from
said digital image of said rock sample using said in situ fluid properties,

l) positioning a logging tool inside a well bore of a similar formation as that of the wellbore of step a),
m) repeating step c) for measuring in situ well properties using the logging tool used in step l),
n) estimating rock properties in the well for a location of the logging tool used in step l) in a well interval using the
measured in situ well properties from step m), and

o) correcting the estimates of rock properties from step n) during the logging process using rock properties or rock property
trends determined from said adjusted digital image in step j).

US Pat. No. 9,142,045

METHOD FOR DISPLAYING TWO-DIMENSIONAL GEOLOGICAL IMAGE DATA IN LOG FORMAT AND DISPLAYED PRODUCT

InGrain, Inc., Houston, ...

1. A method of displaying geological image data, the method comprising:
(a) capturing a plurality of two-dimensional images of different planar slices at different depths through a geological sample
in a sequence, the plurality of two-dimensional images comprising a first dimensional direction and a second dimensional direction
perpendicular to the first dimensional direction, wherein locations of at least one geological phase of the geological sample
are captured;

(b) determining if any of the plurality of two-dimensional images in the sequence are to be replaced with a replacement gap
when joined;

(c) joining the plurality of two-dimensional images and any gaps in the sequence to form a continuous stitched image, wherein
the joining comprises joining in a plane the plurality of images with each image positioned adjacent and below any preceding
image of the sequence;

(d) calculating proportional magnitudes of at least one geological phase based on the total geological phases for each of
a plurality of adjoining rows of pixels in the stitched image, wherein the at least one geological phase comprises pore, kerogen,
mineral, or a combination thereof, and wherein the plurality of adjoining rows of pixels in the stitched image each extend
from corresponding adjacent first positions along the first dimensional direction of the sequential slices in a direction
parallel to the second dimensional direction of the sequential slices; and

(e) plotting the proportional magnitudes calculated for the at least one geological phase for each of the plurality of adjoining
rows of pixels in the stitched image at corresponding first adjacent locations on a first portion of a two-dimensional graph,
wherein the two-dimensional graph comprises a first axis extending in a same direction as the first dimensional direction
and a second axis extending in a same direction as the second dimensional direction, and the first adjacent locations on the
first portion of the two-dimensional graph each comprise a first axis coordinate corresponding to the position of each row
of the pixels and a second axis coordinate corresponding to the proportional magnitude for the corresponding row of pixels.

US Pat. No. 9,046,509

METHOD AND SYSTEM FOR ESTIMATING ROCK PROPERTIES FROM ROCK SAMPLES USING DIGITAL ROCK PHYSICS IMAGING

Ingrain, Inc., Houston, ...

1. A method for estimating a target rock property of a rock sample from an application of digital rock physics in 2D, comprising:
scanning a rock sample to obtain a 2D digital image of the rock sample;
segmenting the digital image to produce a digital 2D segmented image having pixels characterized as pore space and pixels
characterized as mineral matrix and defining a boundary at the intersection of pore space and the mineral matrix;

deriving values for rock properties P1-P1 from the segmented image as a function of pore space geometry; and

applying a transform relationship adapted for application to a 2D segmented image environment to calculate an estimated value
for a target rock property as a function of pore space geometry derived from the 2D segmented image, wherein the target rock
property is absolute permeability, wherein the transform relationship is adapted by deriving a transform that is wholly a
function of pore space geometry, and wherein the transform relationship further comprises a Kozeny-Carman equation and adaptation
further comprises converting the property of tortuosity to one or more functions of pore space geometry.

US Pat. No. 9,396,547

OUTPUT DISPLAY FOR SEGMENTED DIGITAL VOLUME REPRESENTING POROUS MEDIA

Ingrain, Inc., Houston, ...

1. An output display device coupled to a computer which includes a processor with at a memory storing instructions for displaying
a segmented digital volume representing a sample of a porous media comprising:
a) voxels representing pore space derived from segmentation of a 3D grey scale digital image;
b) voxels representing at least one solid material phase derived from segmentation of the 3D grey scale digital image; and
c) converted voxels representing structural features not fully resolved in the 3D grey scale digital image or the direct segmentation
thereof, wherein the structural features are cracks or conduits unresolved in the 3D grey-scale digital image and contributing
pore space connectivity present in the porous media not accounted for in a preliminary segmentation of the 3D grey-scale digital
image, and the converted voxels represent additional pore space, wherein:

the placement of the converted voxels is derived from additional processing steps using data from the 3D grey-scale digital
image and one or more segmented volumes derived therefrom; and

the volume of converted voxels in place is solved to satisfy a criteria relation representative of the sample and independent
of the 3D grey-scale image.

US Pat. No. 9,201,026

METHOD AND SYSTEM FOR ESTIMATING PROPERTIES OF POROUS MEDIA SUCH AS FINE PORE OR TIGHT ROCKS

Ingrain, Inc., Houston, ...

1. A method for estimating selected physical properties of a rock sample, comprising:
(a) preparing a rock sample,
(b) creating a digital image of the rock sample by scanning the rock sample,
(c) estimating selected physical properties of the rock sample from the digital image of the rock sample,
(d) determining if the digital image provides sufficient detail for estimation of final rock properties, wherein step (e)
directly follows step (d) if sufficient detail is not determined to be provided and step (j) directly follows if sufficient
detail is determined to be provided, wherein steps (e) through (i) are used at least once,

(e) identifying one or more regions within the rock sample that contain high porosity and/or organic matter content,
(f) selecting subsamples of the rock sample that contain high porosity and/or organic content,
(g) preparing rock subsamples from the selected subsamples,
(h) increasing the resolution of the scanning of the rock sample,
(i) repeating steps (b) through (d) until a desired resolution is achieved, and
(j) estimating final rock properties.

US Pat. No. 9,285,301

DIGITAL ROCK ANALYSIS SYSTEMS AND METHODS WITH RELIABLE MULTIPHASE PERMEABILITY DETERMINATION

INGRAIN, INC., Houston, ...

1. A multiphase permeability determination method performed by one or more computers, the method comprising:
obtaining a three-dimensional pore and matrix model of a rock formation sample based on digital imaging of the sample using
a scanning microscope;

determining an axis of flow passing through said sample, wherein the determination is based on the orientation of the sample,
formation pressure gradiens, or user specifications;

verifying that the dimension of the model along said axis exceeds that of a representative elementary volume (REV);
selecting a direction of the flow;
extending said model by mirroring if pore statistics at a given saturation are mismatched for different percolating phases;
increasing a resolution of digital imaging of the sample and repeating said obtaining, determining, verifying, selecting,
extending, and increasing, if a smallest non-percolating sphere dimension is below a predetermined threshold;

measuring relative permeability of said sample using the model; and
providing the relative permeability measurements to a user interface for display to a user.

US Pat. No. 9,741,106

COMPUTED TOMOGRAPHY (CT) SYSTEMS AND METHODS ANALYZING ROCK PROPERTY CHANGES RESULTING FROM A TREATMENT

INGRAIN, INC., Houston, ...

1. A method that comprises:
capturing pre-treatment computed tomography (CT) images of a rock sample comprising at least one sub-sample portion and a
remainder portion, wherein the pre-treatment CT images are captured while the at least one sub-sample portion and the remainder
portion are physically separated;

capturing post-treatment CT images of the at least one sub-sample portion and the remainder portion while physically separated,
wherein the treatment comprises a permeability or porosity adjustment treatment that is applied while the at least one sub-sample
portion and the remainder portion are rejoined together;

comparing at least some of the pre-treatment CT images with respective post-treatment CT images; and
generating a report that describes the treatment's effect based on said comparison.

US Pat. No. 9,746,431

METHOD AND SYSTEM FOR MULTI-ENERGY COMPUTER TOMOGRAPHIC CUTTINGS ANALYSIS

Ingrain, Inc., Houston, ...

1. A method for estimating selected physical properties of a rock sample, which comprises the steps of:
(a) positioning rock fragments of the same drilling interval in spaced positions in a casting container,
(b) introducing flowable polymer into the casting container to encapsulate the rock fragments,
(c) hardening the polymer to form a rock fragments-embedded carrier,
(d) removing the rock fragments-embedded carrier from the casting container,
(e) performing a multi-energy X-ray CT scan of the rock fragments-embedded carrier with at least 3 reference objects,
(f) creating digital images of the rock fragments from the multi-energy X-ray CT scan, wherein each of the rock fragments
scanned at two or more different energy levels returns a CT value for each voxel thereof,

(g) estimating the bulk density, RhoB, and effective atomic number, Zeff, for each of the rock fragments as data pairs based on the digital images of the rock fragments, comprising averaging the
voxels for each entire rock fragment per different energy scan and processing the average values for each rock fragment to
provide the data pairs,

(h) categorizing the bulk density, RhoB, and effective atomic number, Zeff, data pairs into a single set for a single rock fragments-embedded carrier or separate subsets if more than one rock fragments-embedded
carrier of differing intervals is scanned in step (e),

(i) selecting at least one rock fragment from the set or subsets as applicable for further digital analysis,
(j) extracting the at least one selected rock fragment from the carrier,
(k) creating 2D digital images of the selected rock fragment using an SEM,
(l) estimating at least one of porosity, organic matter content, and mineralogy from the images created in step (k),
(m) selecting a subarea of the images created in step (k), which can comprise at least one of relatively high porosity and
high organic matter or other features of interest,

(n) imaging the selected subarea of step (m) with a FIB-SEM,
(o) creating 3D digital images from the imaging in step (n),
(p) segmenting the 3D digital images of step (o) to identify voxels as pore, rock or organic matter, and
(q) estimating rock properties from the segmented images.

US Pat. No. 9,791,431

CUTTINGS-BASED WELL LOGGING

Ingrain, Inc., Houston, ...

1. A method for cuttings-based well logging, the method comprising:
converting measurements of cuttings samples from one or more depth intervals of a wellbore to a concentration percent of one
or more elements;

determining a one or more minerals of the cuttings samples from the concentration percent;
building a mineralogy model for the cuttings sample based at least in part on a gravimetric conversion of the concentration
percent of at least some of the one or more elements to a concentration percent of the one or more minerals;

normalizing the concentration percent of the one or more minerals;
computing a photo-electric absorption factor (PEF) of the cuttings samples for each of the one or more depth intervals; and
presenting to a user a log of the computed PEF as a function of wellbore depth.

US Pat. No. 9,921,334

COMBINING MULTIPLE ENERGY X-RAY IMAGING AND WELL DATA TO OBTAIN HIGH-RESOLUTION ROCK, MECHANICAL, AND ELASTIC PROPERTY PROFILES

Ingrain, Inc., Houston, ...

1. A method for evaluating a geological formation, comprising:
(a) determining a first parameter comprising photoelectric effect index, effective atomic number, or bulk density, and a target
parameter comprising a formation property that is different from the first parameter, for a rock sample at a depth interval
in a formation, using formation data;

(b) repeating (a) for at least one additional depth interval in the formation;
(c) curve-fitting the first parameter and the second parameter determined for the depth intervals of (a)-(b) to generate at
least one of a mathematical function equation or cross-plot thereof relating the first and target parameters;

(d) generating a tomographic image of a rock sample obtained from a depth interval in the formation for generating a digital
image of the rock sample;

(e) determining photoelectric effect index, effective atomic number, or bulk density in correspondence to the first parameter
used in the curve-fitting in (c) for the rock sample of (d), using the digital image generated for the rock sample in (d);
and

(f) computing a high resolution target parameter for the rock sample of (d) comprising applying the mathematical function
equation or cross-plot of (c) to the photoelectric effect index, effective atomic number, or bulk density determined in (e).

US Pat. No. 10,054,577

METHOD AND SYSTEM FOR OBTAINING GEOCHEMISTRY INFORMATION FROM PYROLYSIS INDUCED BY LASER INDUCED BREAKDOWN SPECTROSCOPY

Ingrain, Inc., Houston, ...

1. A method for analysing a geological sample, comprising:subjecting at least one location of a geological sample to a plurality of successive measurement shots of laser light from a laser with each measurement shot at least partly vaporising and turning a portion of said geological sample into plasma to cause spectral emission;
detecting said spectral emission after each said measurement shot with at least one spectrum detector;
preprocessing of collected data from the at least one spectrum detector to form pre-processed data for analysis, wherein the preprocessing comprises one or more of:
integration of one or more peak areas to produce an intensity curve or curves, or
selection of the actual peak spectra for successive measurement shots, or
selection of sub-regions of the spectra for the successive measurement shots, or
selection of the whole spectra for the successive measurement shots; and
determining bitumen content of the geological sample, kerogen content of the geological sample, or both using the pre-processed data from the at least one spectrum detector.
US Pat. No. 10,113,952

COMBINED VIBRATIONAL SPECTROSCOPY AND LASER INDUCED BREAKDOWN SPECTROSCOPY FOR IMPROVED MINERALOGICAL AND GEOCHEMICAL CHARACTERIZATION OF PETROLEUM SOURCE OR RESERVOIR ROCKS

Ingrain, Inc., Houston, ...

1. A method for determining mineralogy or geochemistry of a sample of a petroleum source or reservoir rock, comprising:a) obtaining one set of spectral data comprising vibrational spectral data on the sample;
b) obtaining another set of spectral data comprising LIBS spectral information on the sample, or a second sample of the petroleum source or reservoir rock that has a similar composition and structure;
c) obtaining mineralogical information or geochemical information on the sample using the two sets of spectral data
d) obtaining spatial information on the sample, using a vibrational spectroscopy measurement device or a LIBS measurement system; and
e) determining spatially resolved geochemical information for the sample using the mineralogical information or geochemical information and the spatial information.