Saudi Arabian Oil Company

Baker Hughes Corporation

David J Jacobi

Katherine Leigh Hull

Younane N Abousleiman

Shannon Lee Eichmann

John Longo

Ghaithan Al-Muntasheri

Yanhui Han

Poorna Srinivasan

Leiming Li

Hasmukh A Patel

Ghaithan Muntasheri

Songhua Chen

Daniel T Georgi

Jose Oliverio Alvarez

Gary Eppler

Freddy Mendez

Brian J LeCompte

Joshua Brothers

John M Longo

Sebastian Csutak

Max Deffenbaugh

Mohammad Hamidul Haque

Weichang Li

Richard R Pemper

Xiaogang Han

Gabor Hursan

Rajesh Goteti

Madhumita Sengupta

Mikhail N Gladkikh

See Hong Ong

Tiffany Dawn McAlpin

Ji Soo Lee

Constantin Sandu

Qiushi Sun

Gary A Feuerbacher

Mikhail A Fedorin

Alfred I Khisamutdinov

Mohamed Soua

Jose Antonio Estevez Gonzalez

Jordan Kone

Ghaithan A Al-Muntasheri

A method for subsurface sequestration of carbon dioxide includes placing into a subterranean zone an oxidizer having a redox potential of at least 0.5 volts. The subterranean zone has an average total organic content of at least three weight percent. Carbon dioxide is injected into the subterranean zone via one or a plurality of wells. A total volume of all fluids injected into the subterranean zone via the one or the plurality of wells includes, on average per well per month, at least sixty-five weight percent carbon dioxide and less than thirty weight percent water.

Sequestration of carbon dioxide in organic-rich geological formations

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 for subsurface sequestration of carbon includes injecting a treatment composition comprising a mineralization accelerant into a subterranean zone at least partially saturated with saline water. The mineralization accelerant is reactive with carbon dioxide to form bicarbonate. The method further includes injecting carbon in the form of carbon dioxide into the subterranean zone and sequestering at least a portion of the carbon in the subterranean zone by precipitation in the subterranean zone of a carbonate mineral formed from reaction of the bicarbonate with metal cations dissolved in the saline water. At least a portion of the bicarbonate is formed by reaction of the mineralization accelerant with the carbon dioxide.

Sequestration of carbon in saline aquifers

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

The subject matter of this specification can be embodied in, among other things, a method for treating a geologic formation that includes providing a hydraulic fracture model, providing a first value representative of a volume of kerogen breaker in a fracturing fluid, determining a discrete fracture network (DFN) based on the hydraulic fracture model and the first value, determining a geomechanical model based on the DFN and a reservoir model based on the DFN, determining a hydrocarbon production volume based on the geomechanical model and the reservoir model, adjusting the first value based on the hydrocarbon production volume, and adjusting a volume of kerogen breaker in the fracturing fluid to a hydrocarbon reservoir based on the adjusted first value.

Hydraulic fracturing in kerogen-rich unconventional formations

The disclosure relates to a source productivity assay integrating pyrolysis data and X-ray diffraction data.

Source productivity assay integrating pyrolysis data and X-ray diffraction data

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

A synthetic source rock including roasted tea powder and inorganic material. A technique for preparing the synthetic source rock, including grinding tea leaves to give tea powder, roasting the tea powder at a roasting temperature to give a roasted tea powder, and determining composition and porosity of the roasted tea powder.

Synthetic source rock with tea

Methods, systems, and computer-readable medium to perform operations for identifying fracture barriers in a well. The operations include converting rebound hardness values of a rock specimen from the well to unconfined compressive strength (UCS) values, where each of the rebound hardness values corresponds to a respective coordinate of a measurement grid imposed on the specimen. The operations further include, for each column of the grid, plotting the UCS values versus depth. Further, the operations include mapping, based on a maximum UCS value and a minimum UCS value, a relative strength contour plot for the specimen. Yet further, the operations include mapping, based on a fixed strength range, an absolute strength contour plot for the specimen. In addition, the operations include determining, based on the relative strength contour, the absolute strength contour, and mineralogy of the rock specimen, that the rock specimen is indicative of a fracture barrier in the well.

Identifying fracture barriers for hydraulic fracturing

Methods are provided for determining a depositional environment of a sample of a subterranean environment. An example method includes measuring intensities for a crystallographic plane (CP) 100 peak and a CP 101 peak for quartz in a diffractogram, calculating a ratio of the intensities of the CP 100 peak to the CP 101 peak, and identifying a depositional environment for the sample from the ratio.

Determination of depositional environments

The present disclosure is directed to numerically estimating the shear modulus of Kerogen by using a combination of mineralogy from digital image analysis and sonic log analysis, when measured data on only one elastic constant (Bulk, Young's or P-wave modulus) is available. In some instances, elastic properties predicted from the digital images are compared with sonic, shear, and density logs, to estimate the shear modulus of kerogen. As a one-to-one correspondence is not expected between the core sub-samples and the rock unit sampled by the well logs, cross-property relations can be used to identify the suitability of the effective medium models and to iteratively determine the shear modulus of kerogen.

Method of estimating elastic properties of kerogen using multi-scale data integration

Embodiments of the disclosure provide a method of determining the presence of a hydrocarbon in an aqueous medium used for secondary oil recovery. The method includes the step of introducing the aqueous medium into a subterranean hydrocarbon formation to displace hydrocarbons. The method includes the step of retrieving an aqueous sample from the aqueous medium introduced into the subterranean hydrocarbon formation. The method includes the step of cooling the aqueous sample such that the aqueous sample is in a solid state. The method includes the step of exposing the aqueous sample to an electromagnetic wave at a microwave frequency such that a scattering response is induced from the hydrocarbon included in the aqueous sample. The method includes the step of determining permittivity of the hydrocarbon based on the scattering response.

Method for measuring oil in water using multi-frequency microwave measurements

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

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The Woodlands, TX, United States of America

David J Jacobi