Saudi Arabian Oil Company

Boston University

Aramco Services Company

Shannon Lee Eichmann

Hooisweng Ow

David J Jacobi

Jason R Cox

Howard Khan Schmidt

Katherine Leigh Hull

Wei Wang

Sehoon Chang

Younane N Abousleiman

Tiffany Dawn McAlpin

Constantin Sandu

Sebastian Csutak

Max Deffenbaugh

Mazen Kanj

Amr Ismail Abdel-Fattah

Weichang Li

Dmitry Kosynkin

Ayrat Gizzatov

Bennett B Goldberg

Thomas Gary Bifano

Gary Eppler

Poorna Srinivasan

Hari Prasad Paudel

Qiushi Sun

Joshua Brothers

William Shain

Mohammad Alaskar

Systems and methods for evaluating source rock include: a reactor vessel comprising a body with an internal cavity sized to receive a sample holder, a heating system, a radiation source and a detector bracketing the reactor vessel, wherein the radiation source, the detector, and the reactor vessel are rotatable relative to each other; and a processor in communication with the detector, the processor causing performance of operations comprising: obtaining a plurality of measurements of a source rock sample; generating a conceptual model of the source rock sample based on the plurality of measurements obtained; and determining one or more properties of the source rock sample based on the conceptual model.

Evaluating source rock based on time series analysis

A method of treating a subsurface formation with a coated proppant includes introducing the first hydraulic fracturing composition into a wellbore and the subsurface formation through a first zone of the plurality of zones of the subsurface formation; propagating at least one subsurface fracture in the first zone with the first hydraulic fracturing composition, and wherein the hydraulic fracturing composition includes a fluid medium and a first coated proppant dispersed within the fluid medium, the first coated proppant including: a particulate substrate; a first polymeric layer surrounding the particulate substrate, the first polymeric layer including a first chemical additive; and a second polymeric layer surrounding the first polymeric layer, the second polymeric layer including a first chemical tracer, the first chemical tracer including barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, paramagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, or time-resolved fluorescence resonance energy transfer polymer-nanoparticles (TR-FRET).

Method of treating a subsurface formation with a coated proppant

A coated proppant including a particulate substrate, a first polymeric layer surrounding the particulate substrate, and a second polymeric layer surrounding the first polymeric layer. The first polymeric layer may include chemical additives. The second polymeric layer may include chemical tracers. The chemical tracers include barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, superparamagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, time-resolved fluorescence resonance energy transfer polymer-nanoparticles (TR-FRET), or combinations thereof.

Composition for a coated proppant

A method of analyzing a geologic sample includes illuminating the geologic sample with a light beam and capturing an image of the geologic sample on a hyperspectral camera as a greyscale image, R-G-B color space image, or both, thereby collecting spectra having mid-wave infrared wavelengths or ultraviolet wavelengths reflected from a surface of the geologic sample. The method further includes processing the image to transform the image from the R-G-B color space, greyscale image, or both, and analyzing the Intensity to determine mineralogy, organic content, hydrocarbon presence, or combinations thereof of the geologic sample.

Methods of geologic sample analysis

A method for evaluating a rock permeability is disclosed. The method includes generating a binary 2D field of view image; selecting a plurality of regions from the generated image; locating a plurality of pores from the plurality of image seeds; collecting pore data for each pore of the plurality of pores; characterizing the pore data for each pore of the plurality of pores; storing pore data for each pore from the plurality of pores; choosing an image seed of the plurality of image seeds as an initial slice of the 3D image model of the source rock; modulating the pore data for each pore of the plurality of pores relative to the plurality of pores from each image seed of the plurality of image seeds; generating and combining the plurality of new images into a 3D volume to generate the 3D image model of the source rock.

Evaluating source rock permeability using 3D model

A pyrolysis system for evaluating a source rock sample from a subterranean reservoir and methods are described. The pyrolysis system includes a reactor vessel including a body with an open end, a cover attachable to the body, a heating system, a collector assembly. The body and the cover define a sealable chamber; a source rock sample holder sized to be received inside the sealable chamber; and a sensor system. The sensor system includes a direct sensor assembly associated with the source rock sample holder, sized to be received inside the sealable chamber, and operable to measure properties of the source rock sample in the source rock sample holder; and a pyrolysis products sensor assembly in fluid communication with the collector assembly of the reactor vessel.

Evaluation of source rock samples from subterranean reservoirs

A method of determining a thermal maturity model of a subterranean region of interest is disclosed. The method includes obtaining a plurality of rock samples for the subterranean region of interest. The method further includes determining a first porosity value, a second porosity value, and a volume fraction of organic matter, for each of the plurality of rock samples. The method further includes determining, for each of the plurality of rock samples, a thermal maturity index based, at least in part, on the first porosity value, the second porosity value and the volume fraction of organic matter. The method further includes determining the thermal maturity model based, at least in part, on the thermal maturity index for each of the plurality of rock samples.

Method to determine relative thermal maturity from porosities measured by quantitative imaging on uncleaned samples and GRI porosity measured on crushed cleaned samples

A mounting device for holding a sample mounted to a sample holder for use in an inverted microscope. The mounting device includes a platen; a mounting located on a sample side of the platen; a sample holder removably coupled to the mounting so the sample is along an optical axis of the inverted microscope; and a spacer shaped as a hollow prism or a hollow cylinder having a height and defining a through hole. The platen is disposed on the spacer with the sample side facing toward the spacer and the sample holder positioned within the through hole. The height of the spacer arranges the sample within a focal plane of the inverted microscope.

Sample holder for using mounted SEM samples in upright and inverted optical microscopes and spectrometers

Systems, apparatuses, and computer-implemented methods are provided for the sensing and prediction of properties of source rock. Disclosed here is a method of predicting the maturity of a source rock that includes obtaining a plurality of data of a sample source rock from a plurality of data acquisition devices placed in vicinity of the sample source rock and analyzing the received data using a predictive correlation to determine maturity of the sample source rock. The predictive correlation is generated by applying a machine learning model to correlate the plurality of data acquired from a plurality of representative source rocks with a plurality of properties of the plurality of representative source rocks.

Collaborative sensing and prediction of source rock properties

A system and method for evaluating a geological formation including subjecting a source-rock sample from the geological formation to atomic force microscopy (AFM) to determine a thermal property or material property of the source-rock sample. The properties determined may include thermal conductivity or material transition temperature.

Thermal analysis for source rocks

Disclosed here compositions and methods suitable for injection of a nanosurfactant-containing fluid into a hydrocarbon-bearing formation for enhanced recovery operations. Embodiments of the composition contain a petroleum sulfonate surfactant, mineral oil, and a zwitterionic co-surfactant.

Nanosurfactants for improved and enhanced oil recovery applications

A composition including a coated nanoparticle including a nanoparticle and a cross-linked carbohydrate-based coating and an ion selected from the group consisting of Li, Na, K, Rb, Cs, Be, Mg, Ca, Sr, Ba, and mixtures thereof; methods of making and using the composition; and systems including the composition.

Polysaccharide coated nanoparticle compositions comprising ions

A system and method for evaluating kerogen-rich shale (KRS) including measuring, via scanning microscopy, electrical conductivity of a KRS sample and a mechanical property of the KRS sample.

Growing community of inventors

Somerville, MA, United States of America

Shannon Lee Eichmann